Docket EPA-HQ-OAR-2002-0058 

Attached are 9 corrections to existing data and new data submitted after 3/31/10. 

Data will be reviewed and considered in the promulgated rule. 
Attachment 1
From: Derrick Dease <Derrick.Dease@ipaper.com>

To: <eddinger.jim@epa.gov>, <shrager.brian@epa.gov>

CC: <spells.charlene@epa.gov>, <amanda.singleton@erg.com>, 

<Tim_Hunt@afandpa.org>, <Amy_Marshall@URSCorp.com>

Date: 4/1/2010 3:42 PM

Subject: International Paper's Corrections to the ICR Boiler MACT Database

Attachments: pic15404.jpg; International Paper's Corrections-Boiler MACT Database 04-01-10.doc; 

Boiler MACT Database Corrections for International Paper 04-01-10.xlsx; NYIntPaperTiconderoga Stack 

Testing Report - Body Part 1.PDF; InternationalPaper-PrattvilleMill_EmissionTestSpreadsheet_PB1 and 

PB2 ParticulateMatter.xlsx; International Paper - Eastover Mill - Transmittal of Revised Survey.PDF

For review....

------------------------------------------------------------------

(Embedded image moved to file: pic15404.jpg)

 INTERNATIONAL PLACE 3

 6400 POPLAR AVENUE

 MEMPHIS, TN 38197

 PHONE (901) 419-9000

April 1, 2010

Mr. Jim Eddinger

U.S. Environmental Protection Agency

OAQPS, Sector Policies and Program Division (D243-01)

Research Triangle Park, North Carolina 27711

Mr. Brian Shrager

U.S. Environmental Protection Agency

OAQPS, Sector Policies and Program Division (D243-01)

Research Triangle Park, North Carolina 27711

Re: International Paper’s Corrections to the ICR Boiler MACT Database

Dear Mr. Eddinger and Mr. Shrager:

International Paper (IP) is providing corrections to the EPA ICR Boiler

MACT database. For ease of reference, this letter is divided into the

relevant subject areas requiring corrections and/or updates.

Closed Facilities to be Removed from the Database

The following facilities are now closed, and we request that they be

removed from the ICR Database.

· International Paper Albany Mill (Facility ID: ORIPAlbanyMill)

· International Paper Franklin Mill (Facility ID:

VAInternationalPaperFranklin) to close on April 15, 2010

Contact Information Corrections/Updates (“Data _Facility” tab)

Update the contact information for the following facilities as the
individuals listed in the database are either no longer with the company or

their position has changed. A detailed update to this contact information

is provided in the attached spreadsheet, Boiler MACT Database Corrections

for International Paper 04-01-10, “Data_Facility” tab.

· International Paper Pine Hill Mill (Facility ID: ALIPPineHill)

primary contact is Kyle Moore.

· International Paper Pensacola Mill (Facility ID: FLIPPensacola)

primary contact is Rusty Plenkers.

· International Paper Georgetown Mill (Facility ID: SCIPGeorgetown)

primary contact is Jacquelyn Taylor

Emissions Data Corrections/Updates (“DataEmissions Test” tab)

Update the Boiler MACT database for the following facilities as described

more fully in the attached spreadsheet, Boiler MACT Database Corrections

for International Paper 04-01-10, “DataEmissionsTest” tab.

· International Paper Ticonderoga Mill (Facility ID:

NYIntlPaperTiconderoga) – Dioxin/Furan data flagged for PB1 as "Not Able to

Convert". Data is available in ug/dscm. See attached file entitled,

“NYIntPaperTiconderoga Stack Testing Report-Body Part 1”, Table 3-11, page

23.

· International Paper Prattville Mill (Facility ID: ALIPPrattville) -

PM data for 2003-2007 (No. 1 Power Boiler) was missing from the database.

Likewise, PM data for 2003-2008 (No. 2 Power Boiler) was missing from the

database. See attached emission test spreadsheet entitled,

"InternationalPaper-PrattvilleMill_EmissionTestSpreadsheet_PB01 and PB02

ParticulateMatter.xlsx".

· International Paper Eastover Mill (Facility ID:

SCInternationalPaperEastover) - PM was incorrectly reported as "Particulate

Matter (total, including condensibles)" rather than "Particulate Matter

(filterable)". This was previously reported on February 24, 2010 but has

not been corrected as of Version 4 of the database. See attached Eastover

memo.

· International Paper Courtland Mill (Facility ID: ALIPCourtland) -

Beryllium was incorrectly reported in the database as 9.27E-9 lb/M2Btu

rather than 9.79E-9 lb/M2Btu for the 2009 test.

Additional Corrections (“Data_Unit_Design_Operation” tab)

In addition to the data corrections above, IP also believes, the No. 1

Power Boiler at the International Paper Texarkana Mill (Facility ID:

TXInternationalPaperQueenCity) was incorrectly placed in the CISWI

database. As reported in the ICR survey, this is a natural gas fired unit

which also occasionally burns No. 6 fuel oil. The unit is listed in the

CISWI database as burning contaminated biomass and gas with a fuel category

of "Solid -non-coal". This error was previously reported on February 5,

2010 but has not been corrected as of the most current version of the

database.

Should you have any questions or need additional information, please feel

free to contact me at (901) 419-4355 or via email at

derrick.dease@ipaper.com or Marceia Cox at (901) 419-3930 or
marceia.cox@ipaper.com. Thank you in advance for considering our requests.

Sincerely,

Derrick Dease

EHS Representative, EHS Services

Attachment (4)

Cc: Charlene Spells, EPA

 Amanda Singleton, ERG

 Amy Marshall, URS

 Tim Hunt, AF&PA

 Jeff Shumaker, IP Memphis

 Marceia Cox, IP Memphis

 Sheryl Raulston, IP Franklin

 Kyle Moore, IP Pine Hill

 Rusty Plenkers, IP Pensacola

 Jacquelyn Taylor, IP Georgetown

 Stephen Regan, IP Ticonderoga

 Martha Sims, IP Prattville

 John Baker, IP Eastover

 Russell Foulke, IP Courtland

 Moe Marquis, IP Texarkana

(See attached file: International Paper's Corrections-Boiler MACT Database

04-01-10.doc)

Boiler MACT Database Corrections for International Paper

(See attached file: Boiler MACT Database Corrections for International

Paper 04-01-10.xlsx)

International Paper Ticonderoga Mill Dioxin/Furan Data

(See attached file: NYIntPaperTiconderoga Stack Testing Report - Body Part

1.PDF)
International Paper Prattville Mill PM data

(See attached file:

InternationalPaper-PrattvilleMill_EmissionTestSpreadsheet_PB1 and PB2

ParticulateMatter.xlsx)

International Paper Eastover Mill Memo dated February 24, 2010 requesting

changes to database

(See attached file: International Paper - Eastover Mill - Transmittal of

Revised Survey.PDF)
INTERNATIONAL PLACE 3 

6400 POPLAR AVENUE 

MEMPHIS, TN 38197 

PHONE (901) 419-9000 

April 1, 2010 

Mr. Jim Eddinger 

U.S. Environmental Protection Agency 

OAQPS, Sector Policies and Program Division (D243-01) 

Research Triangle Park, North Carolina 27711 

Mr. Brian Shrager 

U.S. Environmental Protection Agency 

OAQPS, Sector Policies and Program Division (D243-01) 

Research Triangle Park, North Carolina 27711 

Re: International Paper’s Corrections to the ICR Boiler MACT Database 

Dear Mr. Eddinger and Mr. Shrager: 

International Paper (IP) is providing corrections to the EPA ICR Boiler MACT database. For 

ease of reference, this letter is divided into the relevant subject areas requiring corrections and/or 

updates. 

Closed Facilities to be Removed from the Database

The following facilities are now closed, and we request that they be removed from the ICR 

Database. 

• International Paper Albany Mill (Facility ID: ORIPAlbanyMill) 

• International Paper Franklin Mill (Facility ID: VAInternationalPaperFranklin) to close 

on April 15, 2010 

Contact Information Corrections/Updates (“Data _Facility” tab) 

Update the contact information for the following facilities as the individuals listed in the 

database are either no longer with the company or their position has changed. A detailed update 

to this contact information is provided in the attached spreadsheet, Boiler MACT Database 

Corrections for International Paper 04-01-10, “Data_Facility” tab. 

• International Paper Pine Hill Mill (Facility ID: ALIPPineHill) primary contact is Kyle 

Moore. 
International Paper’s Corrections 

To EPA’s ICR Boiler MACT/CISWI Database

Page 2 of 3 

• International Paper Pensacola Mill (Facility ID: FLIPPensacola) primary contact is 

Rusty Plenkers. 

• International Paper Georgetown Mill (Facility ID: SCIPGeorgetown) primary contact 

is Jacquelyn Taylor 

Emissions Data Corrections/Updates (“DataEmissions Test” tab)

Update the Boiler MACT database for the following facilities as described more fully in the 

attached spreadsheet, Boiler MACT Database Corrections for International Paper 04-01-10,

“DataEmissionsTest” tab. 

• International Paper Ticonderoga Mill (Facility ID: NYIntlPaperTiconderoga) – 

Dioxin/Furan data flagged for PB1 as "Not Able to Convert". Data is available in 

ug/dscm. See attached file entitled, “NYIntPaperTiconderoga Stack Testing ReportBody Part 1”, Table 3-11, page 23. 

• International Paper Prattville Mill (Facility ID: ALIPPrattville) - PM data for 2003-

2007 (No. 1 Power Boiler) was missing from the database. Likewise, PM data for 2003-

2008 (No. 2 Power Boiler) was missing from the database. See attached emission test 

spreadsheet entitled, "InternationalPaper-PrattvilleMill_EmissionTestSpreadsheet_PB01 

and PB02 ParticulateMatter.xlsx". 

• International Paper Eastover Mill (Facility ID: SCInternationalPaperEastover) - PM 

was incorrectly reported as "Particulate Matter (total, including condensibles)" rather than 

"Particulate Matter (filterable)". This was previously reported on February 24, 2010 but 

has not been corrected as of Version 4 of the database. See attached Eastover memo. 

• International Paper Courtland Mill (Facility ID: ALIPCourtland) - Beryllium was 

incorrectly reported in the database as 9.27E-9 lb/M2Btu rather than 9.79E-9 lb/M2Btu 

for the 2009 test. 

Additional Corrections (“Data_Unit_Design_Operation” tab)

In addition to the data corrections above, IP also believes, the No. 1 Power Boiler at the 

International Paper Texarkana Mill (Facility ID: TXInternationalPaperQueenCity) was 

incorrectly placed in the CISWI database. As reported in the ICR survey, this is a natural gas 

fired unit which also occasionally burns No. 6 fuel oil. The unit is listed in the CISWI database 

as burning contaminated biomass and gas with a fuel category of "Solid -non-coal". This error 

was previously reported on February 5, 2010 but has not been corrected as of the most current 

version of the database. 
International Paper’s Corrections 

To EPA’s ICR Boiler MACT/CISWI Database

Page 3 of 3 

Should you have any questions or need additional information, please feel free to contact me at 

(901) 419-4355 or via email at derrick.dease@ipaper.com or Marceia Cox at (901) 419-3930 or 

marceia.cox@ipaper.com. Thank you in advance for considering our requests. 

Sincerely, 

Derrick Dease 

EHS Representative, EHS Services 

Attachment (4) 

Cc: Charlene Spells, EPA 

Amanda Singleton, ERG 

 Amy Marshall, URS 

Tim Hunt, AF&PA 

Jeff Shumaker, IP Memphis 

 Marceia Cox, IP Memphis 

Sheryl Raulston, IP Franklin 

Kyle Moore, IP Pine Hill 

Rusty Plenkers, IP Pensacola 

Jacquelyn Taylor, IP Georgetown 

Stephen Regan, IP Ticonderoga 

Martha Sims, IP Prattville 

John Baker, IP Eastover 

Russell Foulke, IP Courtland 

Moe Marquis, IP Texarkana 

 

 
Data__Facility

Boiler MACT Database Comments for International Paper FacilityID Facility Name 2a_Phys_Address 2b_Phys_City 2c_Phys_State 2d_Phys_Zip 2e_Phys_County

Delete all data related to this facility. This facility is no longer in 

operation. ORIPAlbanyMill International Paper Albany Mill 3251 Old Salem Road Albany OR 97321 Linn

Facility contact is no longer with the company. Please change from Perry 

Dargitz to Kyle Moore as indicated in red bold lettering. ALIPPineHill International Paper - Pine Hill Mill 7600 Highway 10 East Pine Hill AL 36769 Wilcox

Facility contact has changed. Please change from Mike Steltenkamp to 

Rusty Plenkers as indicated in red bold lettering. FLIPPensacola International Paper - Pensacola Mill 375 Muscogee Road, PO Box 87 Cantonment FL 32533 Escambia

Facility contact has changed. Please change from Gary Weinreich to 

Jacquelyn Taylor as indicated in red bold lettering. SCIPGeorgetown International Paper - Georgetown Mill 700 South Kaminski Street Georgetown SC 29440 Georgetown

Page 1
Data__Facility

3a_ContactName 3b_ContactTitle 3c_Telephone 3d_Fax 3e_E-mail 4_FacilityLegalName 5_AffectedSector 6_MajororArea

Scott Freeburn Environmental Director Albany/Springfield 541-924-4654 541-924-4628 scott.freeburn@cbpr.ipaper.com Private Enterprise True

Perry Dargitz

Kyle Moore Environmental EHS Manager

(334) 963-4391

(334) 963-2307

(334) 963-2773

(334) 963-2703

perry.dargitz@cbpr.ipaper.com

kyle.moore@ipaper.com Private Enterprise True

Mike Steltenkamp

Rusty Plenkers Environmental Manager

850-968-4868

(850) 968-4212 850-968-3068

mike.steltenkamp@ipaper.com

rusty.plenkers@ipaper.com Private Enterprise True

Gary Weinreich

Jacquelyn Taylor Environmental Manager 

843-545-2291

843-545-2290 843-545-2480

gary.weinreich@ipaper.com

jacquelyn.taylor@ipaper.com Private Enterprise True

Page 2
Data__Facility

7a1_NumberCompanyEmployees 7a2_NumberFacilityEmployees 7b1_Population 8_Small Entity 9_NAICS NACAA?

>1000 100-499 False 322

>1000 100-499 False 322

>1000 100-499 False 322

>1000 500-999 False 322

Page 3









































PM and Metals PB1(1)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/11/03 6/11/03 6/11/03

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 307 352 346 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 481 545 537 mmBtu/hr

Wood: Bark 32.8 33.7 33.6 Other: Please Explain tons/hour

If other fuel type is selected please specify in this cell

Natural gas (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.025 0.02 0.035 0.026 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Prattville Mill

No. 1 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 
PM and Metals PB1(2)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 11/9/04 11/9/04 11/9/04

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 285 273 284 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 453 436 451 mmBtu/hr

Wood: Bark 34.2 34.4 33.9 Other: Please Explain tons/hour

If other fuel type is selected please specify in this cell

Natural gas (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.028 0.026 0.023 0.026 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

No. 1 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Prattville Mill
PM and Metals PB1(3)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 9/28/05 9/28/05 9/28/05

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 278 265 276 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 440 420 431 mmBtu/hr

Wood: Bark 32.9 31.2 28.2 Other: Please Explain tons/hour

If other fuel type is selected please specify in this cell

Natural gas (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.021 0.087 0.018 0.042 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

No. 1 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Prattville Mill
PM and Metals PB1(4)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 12/7/06 12/7/06 12/7/06

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 295 295 319 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 458 468 472 mmBtu/hr

Wood: Bark 33.5 33.5 36.3 Other: Please Explain tons/hour

If other fuel type is selected please specify in this cell

Natural gas (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.025 0.026 0.016 0.023 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

No. 1 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Prattville Mill
PM and Metals PB1(5)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 5/17/07 5/17/07 5/17/07

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 196 216 207 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 480 483 459 mmBtu/hr

Wood: Bark 37.7 41.6 39.9 Other: Please Explain tons/hour

If other fuel type is selected please specify in this cell

Natural gas (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.015 0.015 0.026 0.019 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

No. 1 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Prattville Mill
PM and Metals PB1

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 5/27/08 5/27/08 5/27/08

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 259 253 250 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 391 390 390 mmBtu/hr

Natural gas 134 64 29 mmBtu/hr Gas Fuel Meter

If other fuel type is selected please specify in this cell

Wood: Bark 257 326 361 mmBtu/hr Boiler Effciency Calc

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.027 0.014 0.014 0.018 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 25.6 24.8 24.3

Exhaust Flowrate 116635 116819 119153 dscfm

Exhaust Temperature 154 152 150 F

International Paper Prattville Mill

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

No. 1 Power Boiler

As listed in question II.B.3.a1
PM and Metals PB2 (1)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 2/18/03 2/18/03 2/18/03

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only)

Total Heat Input (mmBtu/hr) 573 568 565 mmBtu/hr

Coal: Bituminous 4.5 4.1 5.4 tons/hr

If other fuel type is selected please specify in this cell

Wood: Bark 56.9 57.6 53 tons/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.019 0.027 0.026 0.024 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

No. 2 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

Inernational Paper Prattville Mill
PM and Metals PB2 (2)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/8/04 6/8/04 6/8/04

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only)

Total Heat Input (mmBtu/hr) 587 596 625 mmBtu/hr

Coal: Bituminous 8.1 6.9 6.9 tons/hr

If other fuel type is selected please specify in this cell

Wood: Bark 47.3 52.2 55.8 tons/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.039 0.03 0.041 0.037 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

No. 2 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

Inernational Paper Prattville Mill
PM and Metals PB2 (3)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/16/05 6/16/05 6/16/05

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only)

Total Heat Input (mmBtu/hr) 551 481 535 mmBtu/hr

Coal: Bituminous 11.7 12.7 11 tons/hr

If other fuel type is selected please specify in this cell

Wood: Bark 33.7 21 33.9 tons/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.079 0.107 0.066 0.084 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

No. 2 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

Inernational Paper Prattville Mill
PM and Metals PB2 (4)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/7/06 6/7/06 6/7/06

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only)

Total Heat Input (mmBtu/hr) 556 560 575 mmBtu/hr

Coal: Bituminous 8.1 8 6.7 tons/hr

If other fuel type is selected please specify in this cell

Wood: Bark 40.3 41 46.5 tons/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.037 0.041 0.022 0.033 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

No. 2 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

Inernational Paper Prattville Mill
PM and Metals PB2 (5)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 5/16/07 5/16/07 5/16/07

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only)

Total Heat Input (mmBtu/hr) 537 536 505 mmBtu/hr

Coal: Bituminous 7.5 7.3 6.4 tons/hr

If other fuel type is selected please specify in this cell

Wood: Bark 36.3 37 36.4 tons/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.056 0.032 0.047 0.045 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

No. 2 Power Boiler

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

Inernational Paper Prattville Mill
PM and Metals PB2(6)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 5/21/08 5/21/08 5/21/08

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 353 385 395 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 460 501 500 mmBtu/hr

Coal: Bituminous 231 256 312 mmBtu/hr

If other fuel type is selected please specify in this cell

Wood: Bark 230 244 188 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units) Not Tested - No Data Available

Arsenic (As) (select emission rate units) Not Tested - No Data Available

Beryllium (Be) (select emission rate units) Not Tested - No Data Available

Cadmium (Cd) (select emission rate units) Not Tested - No Data Available

Chromium (Cr) (select emission rate units) Not Tested - No Data Available

Lead (Pb) (select emission rate units) Not Tested - No Data Available

Manganese (Mn) (select emission rate units) Not Tested - No Data Available

Nickel (Ni) (select emission rate units) Not Tested - No Data Available

Selenium (Se) (select emission rate units) Not Tested - No Data Available

Particulate Matter (front half) 0.068 0.049 0.035 0.051 lb/mmBtu Method 1, 2, 3a, 4, 5 Downstream 24.5 lb/hr

Particulate Matter (total, including condensibles) (select emission rate units) Not Tested - No Data Available

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 20.8 15.2 15.4

Exhaust Flowrate 137,319 128,679 124,258 dscfm

Exhaust Temperature 457 464 451 F

Inernational Paper Prattville Mill

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

No. 2 Power Boiler

As listed in question II.B.3.a1










Attachment 2
From: Derrick Dease <Derrick.Dease@ipaper.com>

To: <spells.charlene@epa.gov>

CC: <eddinger.jim@epa.gov>, <shrager.brian@epa.gov>, <amanda.singleton@erg.com>, 

<Tim_Hunt@afandpa.org>, <Amy_Marshall@URSCorp.com>

Date: 4/1/2010 5:13 PM

Subject: International Paper's Corrections to the EPA CISWI Database

Attachments: pic03171.jpg; International Paper's Corrections CISWI Database 04-01-2010.docx; 

CISWI Database Corrections for International Paper 04-01-10.xlsx; IP Riverdale No2 Bark Boiler 

Emissions Test.pdf; IP Mansfield No2 Power Boiler Emissions Test.pdf; IP Red River No2 Hogged Fuel 

Boiler Emissions Test.pdf; International Paper-Texarkana Mill_EmissionTestSpreadsheet.xls

For review.....

-----------------------------------------------------------

(Embedded image moved to file: pic03171.jpg)

INTERNATIONAL PLACE 3

6400 POPLAR AVENUE

MEMPHIS, TN 38197

PHONE (901) 419-9000

April 1, 2010

Ms. Charlene Spells

U.S. Environmental Protection Agency

OAQPS, Sector Policies and Program Division (D243-01)

Research Triangle Park, North Carolina 27711

Re: International Paper’s Corrections to the ICR CISWI Database

Dear Ms. Spells:

International Paper (IP) is providing corrections to the EPA ICR CISWI

database. For ease of reference, this letter is divided into the relevant

subject areas requiring corrections and/or updates.

Closed Facilities to be Removed from the Database

The following facility is now closed, and we request that it be removed

from the ICR Database.

· International Paper Pineville Mill (Facility ID: LAInternational

Paper-Pineville)

Contact Information Corrections/Updates (“CISWI Data _Facility” tab)

Update the contact information for the following facility as the individual

listed in the database is no longer in that position. A detailed update to

this contact information is provided in the attached spreadsheet, CISWI

Database Corrections for International Paper 04-01-10, “CISWI

Data_Facility” tab.
· International Paper Texarkana Mill (Facility ID:

TXInternationalPaperQueenCity) primary contact is Moe Marquis.

Emissions Data Corrections/Updates (“CISWI Data_Emissions_Test” tab)

Update the Boiler MACT database for the following facilities as described

more fully in the attached spreadsheet, CISWI Database Corrections for

International Paper 04-01-10, “CISWI Data_Emissions_Test” tab.

· International Paper Riverdale Mill (Facility ID: ALIPRiverdale) CO

data for 2009 was omitted from the ICR CISWI database (Stack Test Report

dated October 14, 2009). For your review, the title page and the emissions

test summary for this source are provided in the attached document entitled

“IP Riverdale No2 Bark Boiler CO Emissions Test”. This attachment is taken

from the larger emissions test document previously provided to EPA and can

be resubmitted upon request.

· International Paper Mansfield Mill (Facility ID: LAIPMansfield) has

CO data for its No. 2 Power Boiler in ppm. The ICR CISWI database includes

CO test results in lb/hr and lb/MMBtu. This data is available in Table 2-3

of the attached report entitled “IP Mansfield No2 Power Boiler Emissions

Test.

· International Paper Red River Mill (Facility ID:

LAInternationalPaperRedRiverMill) submitted Nickel data for its No. 2

Hogged Fuel Boiler. This data was incorrectly reported in the database as

0.00135 mg/dscm rather than 0.00151mg/dscm. For your review, the title

page and emissions test summary for this source are provided in the

attached document entitled, “IP Red River No2 Hogged Fuel Boiler Emissions

Test”. This attachment is taken from the larger emissions test document

previously provided to EPA and can be resubmitted upon request.

· International Paper Texarkana Mill (Facility ID:

TXInternationalPaperQueenCity) submitted CO data for its Power Boiler No.

2. This data is incorrect in the database based on ICR Phase I, Source Tab

"Organic HAP & CO (2)" and "Organic HAP & CO (3)". For your reference, we

are resubmitting the ICR Phase I emission test spreadsheet, “International

Paper-Texarkana Mill_Emission Test Spreadsheet”. See tabs “Organic HAP &

CO (2)” and “Organic HAP & CO (3)”, respectively.

Additional Corrections (“Data_Unit_Design_Operation” tab)

In addition to the data corrections above, IP also believes, the No. 1

Power Boiler at the International Paper Texarkana Mill (Facility ID:

TXInternationalPaperQueenCity) was incorrectly placed in the CISWI

database. As reported in the ICR survey, this is a natural gas fired unit

which also occasionally burns No. 6 fuel oil. The unit is listed in the

CISWI database as burning contaminated biomass and gas with a fuel category

of "Solid -non-coal". This error was previously reported on February 5,

2010 but has not been corrected as of the most current version of the

database.
Should you have any questions or need additional information, please feel

free to contact me at (901) 419-4355 or via email at

derrick.dease@ipaper.com or Marceia Cox at (901) 419-3930 or

marceia.cox@ipaper.com. Thank you in advance for considering our requests.

Sincerely,

Derrick Dease

EHS Representative, EHS Services

Attachments (5)

Cc: Jim Eddinger, EPA

 Brian Shrager, EPA

 Amanda Singleton, ERG

 Amy Marshall, URS

 Tim Hunt, AF&PA

 Jeff Shumaker, IP Memphis

 Marceia Cox, IP Memphis

 Moe Marquis, IP Texarkana Mill

 Randy Boone, IP Riverdale Mill

 Mike Sherrill, IP Pineville Mill

 James Strange, IP Mansfield Mill

 Larry Morgan, IP Red River Mill

(See attached file: International Paper's Corrections CISWI Database

04-01-2010.docx)

(See attached file: CISWI Database Corrections for International Paper

04-01-10.xlsx)

International Paper Riverdale Emissions Test Summary

(See attached file: IP Riverdale No2 Bark Boiler Emissions Test.pdf)

International Paper Mansfield Emissions Test Report

(See attached file: IP Mansfield No2 Power Boiler Emissions Test.pdf)
International Paper Red River Emissions Test Summary

(See attached file: IP Red River No2 Hogged Fuel Boiler Emissions Test.pdf)

International Paper ICR Phase I Emission Test Spreadsheet

(See attached file: International Paper-Texarkana

Mill_EmissionTestSpreadsheet.xls)
INTERNATIONAL PLACE 3 

6400 POPLAR AVENUE 

MEMPHIS, TN 38197 

PHONE (901) 419-9000 

April 1, 2010 

Ms. Charlene Spells 

U.S. Environmental Protection Agency 

OAQPS, Sector Policies and Program Division (D243-01) 

Research Triangle Park, North Carolina 27711 

Re: International Paper’s Corrections to the ICR CISWI Database 

Dear Ms. Spells: 

International Paper (IP) is providing corrections to the EPA ICR CISWI database. For ease of 

reference, this letter is divided into the relevant subject areas requiring corrections and/or 

updates. 

Closed Facilities to be Removed from the Database

The following facility is now closed, and we request that it be removed from the ICR Database. 

• International Paper Pineville Mill (Facility ID: LAInternational Paper-Pineville) 

Contact Information Corrections/Updates (“CISWI Data _Facility” tab) 

Update the contact information for the following facility as the individual listed in the database is 

no longer in that position. A detailed update to this contact information is provided in the 

attached spreadsheet, CISWI Database Corrections for International Paper 04-01-10, “CISWI 

Data_Facility” tab. 

• International Paper Texarkana Mill (Facility ID: TXInternationalPaperQueenCity) 

primary contact is Moe Marquis. 

Emissions Data Corrections/Updates (“CISWI Data_Emissions_Test” tab)

Update the Boiler MACT database for the following facilities as described more fully in the 

attached spreadsheet, CISWI Database Corrections for International Paper 04-01-10, “CISWI 

Data_Emissions_Test” tab. 
International Paper’s Corrections 

To EPA’s ICR CISWI Database

• International Paper Riverdale Mill (Facility ID: ALIPRiverdale) CO data for 2009 was 

omitted from the ICR CISWI database (Stack Test Report dated October 14, 2009). For 

your review, the title page and the emissions test summary for this source are provided in 

the attached document entitled “IP Riverdale No2 Bark Boiler CO Emissions Test”. This 

attachment is taken from the larger emissions test document previously provided to EPA 

and can be resubmitted upon request. 

• International Paper Mansfield Mill (Facility ID: LAIPMansfield) has CO data for its 

No. 2 Power Boiler in ppm. The ICR CISWI database includes CO test results in lb/hr 

and lb/MMBtu. This data is available in Table 2-3 of the attached report entitled “IP 

Mansfield No2 Power Boiler Emissions Test.

• International Paper Red River Mill (Facility ID: LAInternationalPaperRedRiverMill) 

submitted Nickel data for its No. 2 Hogged Fuel Boiler. This data was incorrectly 

reported in the database as 0.00135 mg/dscm rather than 0.00151mg/dscm. For your 

review, the title page and emissions test summary for this source are provided in the 

attached document entitled, “IP Red River No2 Hogged Fuel Boiler Emissions Test”. 

This attachment is taken from the larger emissions test document previously provided to 

EPA and can be resubmitted upon request. 

• International Paper Texarkana Mill (Facility ID: TXInternationalPaperQueenCity)

submitted CO data for its Power Boiler No. 2. This data is incorrect in the database 

based on ICR Phase I, Source Tab "Organic HAP & CO (2)" and "Organic HAP & CO 

(3)". For your reference, we are resubmitting the ICR Phase I emission test spreadsheet, 

“International Paper-Texarkana Mill_Emission Test Spreadsheet”. See tabs “Organic 

HAP & CO (2)” and “Organic HAP & CO (3)”, respectively. 

Additional Corrections (“Data_Unit_Design_Operation” tab)

In addition to the data corrections above, IP also believes, the No. 1 Power Boiler at the 

International Paper Texarkana Mill (Facility ID: TXInternationalPaperQueenCity) was 

incorrectly placed in the CISWI database. As reported in the ICR survey, this is a natural gas 

fired unit which also occasionally burns No. 6 fuel oil. The unit is listed in the CISWI database 

as burning contaminated biomass and gas with a fuel category of "Solid -non-coal". This error 

was previously reported on February 5, 2010 but has not been corrected as of the most current 

version of the database. 

Should you have any questions or need additional information, please feel free to contact me at 

(901) 419-4355 or via email at derrick.deasemailto:@ipaper.com or Marceia Cox at (901) 419-

3930 or marceia.cox@ipaper.com. Thank you in advance for considering our requests. 

Sincerely, 
International Paper’s Corrections 

To EPA’s ICR CISWI Database

Derrick Dease 

EHS Representative, EHS Services 

Attachments (5) 

Cc: Jim Eddinger, EPA 

Brian Shrager, EPA 

Amanda Singleton, ERG 

 Amy Marshall, URS 

Tim Hunt, AF&PA 

Jeff Shumaker, IP Memphis 

 Marceia Cox, IP Memphis 

 Moe Marquis, IP Texarkana Mill 

Randy Boone, IP Riverdale Mill 

Mike Sherrill, IP Pineville Mill 

James Strange, IP Mansfield Mill 

Larry Morgan, IP Red River Mill 
CISWI Data__Facility

CISWI Database Comments for International Paper FacilityID Facility Name 2a_Phys_Address 2b_Phys_City

Delete all data related to this facility. This facility is no longer in 

operation. LAInternationalPaper-Pineville International Paper-Pineville Mill 300 Williams Lake Rd Pineville

Facility contact has changed. Please change from Doug Wadley to 

Moe Marquis as indicated in red bold lettering. TXInternationalPaperQueenCity International Paper Texarkana Mill 9978 FM 3129 Queen City

Page 1
CISWI Data__Facility

2c_Phys_State 2d_Phys_Zip 2e_Phys_County 3a_ContactName 3b_ContactTitle 3c_Telephone 3d_Fax

LA 71360 Rapides Mike Sherrill EHS Manager 318-441-4332 318-441-4227

TX 75572 Cass

Doug Wadley

Moe Marquis

Manager of Environmental Performance

EHS Manager

903 796-1638

903 796-7101 903 796-1960

Page 2
CISWI Data__Facility

3e_E-mail 4_FacilityLegalName 5_AffectedSector 6_MajororArea 7a1_NumberCompanyEmployees 7a2_NumberFacilityEmployees 7b1_Population

michael.sherrill@ipaper.com Private Enterprise True >1000 100-499

doug.wadley@ipaper.com

moe.marquis@ipaper.com Private Enterprise True >1000 500-999

Page 3
CISWI Data__Facility

8_Small Entity 9_NAICS Lat Lon

False 322 31.28084 -92.347891

False 322 33.195209 -94.127141

Page 4



































































DioxinFurans

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy) 8/13/2003 8/14/2003 8/14/2003

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 464 398 427 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 827 789 844 mmBtu/hr Downstream

Natural gas 53 29.7 29 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 38 31 35 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 13 6 8 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

Other solid: please explain 20 27 27 Other: Please Explain Ton/hr Loading bin screw & conveyor speed calculation

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Dioxin/Furans ND 

[0.000391]

ND 

[0.000284]

ND 

[0.000829]

ND 

[0.000501]

TEQ (ng/dscm @ 7% O2) EPA SW0010 & Method 23, SW3540/8290 Downstream

Results are calculated using 

1989 International Toxic 

Equivalency Factors

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 20.5 20 19.5 %

Exhaust Flowrate 244152 235192 246332 dscfm

Exhaust Temperature 140 140 139 F

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
Organic HAP and CO (3)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy) 8/13/2003 8/14/2003 8/14/2003

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 464 398 427 1000 lb steam/hr Downstream

Heat Input (mmBtu/hr) 827 789 844 mmBtu/hr Downstream

Natural gas 53 29.7 29 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 38 31 35 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 13 6 8 gallon/minute Oil flow meter

If other fuel type is selected please specify here:

Other solid: please explain 20 27 27 Other: Please Explain Ton/hr Loading bin screw & conveyor speed calculation

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

acetaldehyde Not tested- Not tested- Not tested- Not tested-no (select emission rate units) Not tested-no data Not tested-no data

benzene 0.036 0.02 0.0021 0.0257 Other: Please Explain lb/hr EPA 0030 and SW5041A/8260B Downstream

formaldehyde Not tested- Not tested- Not tested- Not tested-no (select emission rate units) Not tested-no data Not tested-no data

toluene 0.0046 0.0046 0.0018 0.00378 Other: Please Explain lb/hr EPA 0030 and SW5041A/8260B Downstream

xylenes 0.0037 0.0046 0.0017 0.0033 Other: Please Explain lb/hr EPA 0030 and SW5041A/8260B Downstream

CO 97 137 135 123 Other: Please Explain ppm@8% EPA Reference Method 10 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Dry

% O2 or other diluent gas (necessary only if CO emission data is 

provided) 11.1 12.5 12.5 % EPA Method Method 3

Downstream

If other diluent gas, please specify gas in this cell

Exhaust Stream %Moisture 20.5 20 19.5 %

Exhaust Flowrate 244152 235192 246332 dscfm

Exhaust Temperature 140 140 139 F

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 
Organic HAP and CO (2)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy) 8/12/2003 8/12/2003 8/12/2003

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 520 520 520 1000 lb steam/hr Downstream

Heat Input (mmBtu/hr) 838.2 838.2 830 mmBtu/hr Downstream

Natural gas 143.4 143 144 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 61.8 60 62 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 15 15 15 gallon/minute Oil flow meter

If other fuel type is selected please specify here:

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

acetaldehyde Not tested- Not tested- Not tested- Not tested- (select emission rate units)

benzene Not tested- Not tested- Not tested- Not tested- (select emission rate units)

formaldehyde Not tested- Not tested- Not tested- Not tested- (select emission rate units)

toluene Not tested- Not tested- Not tested- Not tested- (select emission rate units)

xylenes Not tested- Not tested- Not tested- Not tested- (select emission rate units)

CO 282 375 291 316 Other: Please Explain ppm@8% EPA Reference Method 10 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Dry

% O2 or other diluent gas (necessary only if CO emission data is 

provided) 10.5 10.5 10.7 % EPA Method Method 3

Downstream

If other diluent gas, please specify gas in this cell

Exhaust Stream %Moisture 19.5 19.5 19.5 %

Exhaust Flowrate 247000 247000 247000 dscfm

Exhaust Temperature 140 139 140 F

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
Organic HAP and CO

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy) 4/27/2004 4/27/2004 4/27/2004

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 193 243 258 1000 lb steam/hr Downstream

Heat Input (mmBtu/hr) 362 383 384 mmBtu/hr Downstream

Natural gas 0.006 0.0063 0.0064 standard cubic feet per 

minute (scfm)

Calculation -- one gas fuel meter to 3 boilers

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify here:

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

acetaldehyde Not tested- Not tested- Not tested- (select emission rate units)

benzene Not tested- Not tested- Not tested- (select emission rate units)

formaldehyde Not tested- Not tested- Not tested- (select emission rate units)

toluene Not tested- Not tested- Not tested- (select emission rate units)

xylenes Not tested- Not tested- Not tested- (select emission rate units)

CO <1.0 <1.0 <1.0 <1.0 Other: Please Explain ppm EPA Reference Method 10 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Dry

% O2 or other diluent gas (necessary only if CO emission data is 

provided) 13.1 12.7 12.6 %

EPA Reference Method 3 Downstream

If other diluent gas, please specify gas in this cell

Exhaust Stream %Moisture 4.4 4.5 4.2 %

Exhaust Flowrate 188000 185000 184000 dscfm

Exhaust Temperature 299 300 300 F

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

International Paper Texarkana Mill

PB01

As listed in question II.B.3.a1

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 
Inorganic HAP

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy)

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) (select heat output units)

Total Heat Input (mmBtu/hr) (select heat input units)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Hydrogen Chloride (HCl) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Hydrogen Flouride (HF) Not tested- Not tested- Not tested- Not tested- (select emission rate units)

Chlorine (Cl2) Not tested- Not tested- Not tested- Not tested- (select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Wet or Dry

Exhaust Stream %Moisture

Exhaust Flowrate acfm or dscfm

Exhaust Temperature C or F

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

International Paper Texarkana Mill

(Select Control Configuration)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
PM and Metals (6)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 8/2/2004 8/6/2004 8/10/2004

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 533 566 552 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 943 880 901 mmBtu/hr Downstream

Natural gas 166 211 160 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 81 68 76 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 6.5 7.7 7.9 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.12 0.06 0.082 0.08733333 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Particulate Matter (total, including condensibles) 0.125 0.066 0.088 0.093 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry

Exhaust Stream %Moisture 22 21 22

Exhaust Flowrate 259149 248326 250931 dscfm

Exhaust Temperature 145 142 144 Degrees F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
PM and Metals (5)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/22/2005 6/22/2005 6/22/2005

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 588 541 507 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 940 876 821 mmBtu/hr Downstream

Natural gas 154 134 132 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 81 76 69 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 8 8 9 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.1 0.082 0.101 0.09433333 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Particulate Matter (total, including condensibles) 0.098 0.08 0.101 0.093 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry

Exhaust Stream %Moisture 21 20 20

Exhaust Flowrate 257534 260458 263827 dscfm

Exhaust Temperature 142 141 140 Degrees F

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
PM and Metals (4)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 8/9/2006 8/9/2006 8/9/2006

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 491 478 517 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 831.8 826.4 828 mmBtu/hr Downstream

Natural gas 106.5 131.6 110.2 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 73 69 71 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 8.7 9.6 10.2 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.102 0.086 0.085 0.091 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Particulate Matter (total, including condensibles) 0.107 0.089 0.089 0.095 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry

Exhaust Stream %Moisture 24 23 25

Exhaust Flowrate 264753 255684 260281 dscfm

Exhaust Temperature 147 146 149 Degrees F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
PM and Metals (3)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 8/22/2007 8/22/2007 8/22/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 551 584 561 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 917 983 934 mmBtu/hr Downstream

Natural gas 106.6 128 105.4 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 44.1 48.3 48.5 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 8.1 8.8 8.2 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

Other solid: please explain 22 22 20.6 Other: Please Explain Ton/hr Loading bin screw & conveyor speed calculation

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.081 0.0612 0.078 0.0734 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Particulate Matter (total, including condensibles) 0.092 0.064 0.084 0.0796 lb/mmBtu EPA Method 5B & 29, Appendix B.3 Downstream

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis

Exhaust Stream %Moisture

Exhaust Flowrate

Exhaust Temperature

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
PM and Metals (2)

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 6/23/2005 6/23/2005

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 422 435 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 709 727 mmBtu/hr Downstream

Natural gas 0 0 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 64 66 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 16 16 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) 0.000381 0.000308 0.000345 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream Test not required for

Arsenic (As) 0.0031 0.00117 0.00212 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream compliance. Conducted

Beryllium (Be) 0.000053 0.0000659 0.0000595 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream for comparison against 

Cadmium (Cd) 0.00337 0.00349 0.00343 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream Boiler MACT limits.

Chromium (Cr) 0.00342 0.00344 0.00343 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream

Lead (Pb) 0.0346 0.034 0.0343 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream

Manganese (Mn) 0.23 0.217 0.224 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream

Nickel (Ni) 0.0137 0.0225 0.0181 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream

Selenium (Se) 0.000249 0.00117 0.00071 Other: Please Explain lb/hr EPA Method 5 & 29, Appendix B.2 Downstream

Particulate Matter (front half) Not testedno dataNot testedno data(select emission rate units)

Particulate Matter (total, including condensibles) Not testedno dataNot testedno data(select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry

Exhaust Stream %Moisture 17.7 17.6 %

Exhaust Flowrate 277888 272202 dscfm

Exhaust Temperature 138 139 Degrees F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
PM and Metals

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected 

please describe units in 

column H at right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 8/13/2003 8/14/2003 8/14/2003

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 464 398 427 1000 lb steam/hr Downstream

Total Heat Input (mmBtu/hr) 826 789 844 mmBtu/hr Downstream

Natural gas 53 29.7 29 Other: Please Explain 1000cu ft/hr Gas fuel meter

If other fuel type is selected please specify in this cell

Wood: Bark 38 31 35 Other: Please Explain Ton/hr Fuel meters & boiler efficiency calculation

If other fuel type is selected please specify in this cell

No. 6 Residual oil 13 6 8 gallon/minute Oil flow meter

If other fuel type is selected please specify in this cell

Other solid: please explain 20 27 27 Other: Please Explain Ton/hr Loading bin screw & conveyor speed calculation

Rail tie derived fuel (chips)

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Arsenic (As) 0.007 0.014 0.009 0.01 Other: Please Explain lb/hr EPA Method 5 & 29, & SW3050-6010-7471 Downstream

Beryllium (Be) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Cadmium (Cd) 0.003 0.006 0.005 0.0046 Other: Please Explain lb/hr EPA Method 5 & 29, & SW3050-6010-7471 Downstream

Chromium (Cr) 0.005 0.006 0.005 0.0053 Other: Please Explain lb/hr EPA Method 5 & 29, & SW3050-6010-7471 Downstream

Lead (Pb) 0.072 0.106 0.115 0.097 Other: Please Explain lb/hr EPA Method 5 & 29, & SW3050-6010-7471 Downstream

Manganese (Mn) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Nickel (Ni) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Selenium (Se) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Particulate Matter (front half) 28.08 33.65 39.2 33.64 Other: Please Explain lb/hr EPA Method 5 & 29, & SW3050-6010-7471 Downstream

Particulate Matter (total, including condensibles) Not testedno dataNot testedno dataNot testedno dataNot testedno data(select emission rate units)

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 20.5 20 19.5 %

Exhaust Flowrate 244152 235192 246332 dscfm

Exhaust Temperature 140 140 139 F

International Paper Texarkana Mill

PB02

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in 

brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
Attachment 3
From: Amanda Singleton

To: combustionsurvey

Date: 4/6/2010 4:10 PM

Subject: Fwd: Boiler/Process Heater MACT ICR Submission Correction

Attachments: BLR-1342 EmissionTestSpreadsheet_081408 Corr 04-05-2010.xls

>>> John C deRuyter <John.C.deRuyter@USA.dupont.com> 4/5/2010 7:07 PM >>>

Jim and Amanda- I was looking through the list of mercury emission test results from 

the database and noted our DuPont DeLisle site had an apparent very high Hg 

emission rate. Upon reviewing the emission test report, I found the data submitted 

in the EmissionTestSpreadsheet Excel file to be incorrect. Attached is a corrected 

ICR Phase 1 Excel file submission with the following changes:

Sheet "AF-101 Metals 3-15-16-05": Corrected the three Hg test run emission rates 

from 0.000543, 0.00059, and 0.000474 lb/MMBtu to be 5.57E-6, 5.86E-6, and 4.93E6 lb/MMBtu, respectively. This series of tests was in a common stack with both 

pulverized coal fired boilers operating similarly.

Sheet "AF-101 Inorganic HAP 3-15-16-05": just corrected the Run 3 date from 

3/15/2005 to 3/16/2005.

I apologize for the errors. I doubt this will impact Floor calculations since this does 

not appear to be in the top 12% of performers, but thought we needed to provide the 

correction upon our discovery.

Please contact me with any questions.

Regards, John

John C. deRuyter

Principal Consultant

Energy Engineering

DuPont Engineering & Research Technology

1007 Market St., DuPont 2164-1

Wilmington, DE 19898

Phone- (302) 774-2603

Fax- (302) 355-3971

john.c.deruyter@usa.dupont.comThis communication is for use by the intended recipient and 

contains information that may be Privileged, confidential or copyrighted under applicable law. If you are 

not the intended recipient, you are hereby formally notified that any use, copying or distribution of this email, in whole or in part, is strictly prohibited. Please notify the sender by return e-mail and delete this email from your system. Unless explicitly and conspicuously designated as "E-Contract Intended", this email does not constitute a contract offer, a contract amendment, or an acceptance of a contract offer. This 

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purposes or for transfers of data to third parties. Francais Deutsch Italiano Espanol Portugues Japanese 

Chinese Korean http://www.DuPont.com/corp/email_disclaimer.html
AF-101 PM and Metals 11-15-04

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 11/15/2004 11/16/2004 11/16/2004

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 319.49 291.15 297 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 355.79 324.23 330.75 mmBtu/hr Common Stack for AF-101A and AF-101B

Coal: Bituminous 355.79 324.23 330.75 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.0167 0.01 0.0103 lb/mmBtu Methods 1-5; Test date before ESP DDDDD upgrade

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 8 8 8

Exhaust Flowrate 120,433 112,856 118,681 dscfm

Exhaust Temperature 251 247 253 F

DuPont Titanium Technologies - DeLisle Plant

AF-101 Common Stack (BLR-1342)

As listed in question II.B.3.a6

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
AF-101 PM 3-15-16-05

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/15/2005 3/15/2005 3/16/2005

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 323.57 314.57 322.39 1000 lb steam/hr Common Stack for AF-101A and AF-101B

Total Heat Input (mmBtu/hr) 356.6 352 361 mmBtu/hr

Coal: Bituminous 356.6 352 361 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.0085 0.0195 0.0155 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu Test above done before ESP DDDDD upgrade

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 5 6 7

Exhaust Flowrate 126,527 124,895 128,104 dscfm

Exhaust Temperature 247 245 242 F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

DuPont Titanium Technologies - DeLisle Plant

AF-101 Common Stack (BLR-1342)

As listed in question II.B.3.a6

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
AF-101 Metals 3-15-16-05

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/15/2005 3/15/2005 3/16/2005

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 323.67 315.11 322.19 1000 lb steam/hr Common Stack for AF-101A and AF-101B

Total Heat Input (mmBtu/hr) 359.2 341.5 365 mmBtu/hr

Coal: Bituminous 359.2 341.5 365 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) 0.00000557 0.00000586 0.00000493 lb/mmBtu ASTM D6784-02 "Ontario Hydro"

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) lb/mmBtu

Particulate Matter (total, including condensibles) lb/mmBtu Test above done before ESP DDDDD upgrade

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 6 7 6

Exhaust Flowrate 127,464 121,179 129,522 dscfm

Exhaust Temperature 247 247 243 F

DuPont Titanium Technologies - DeLisle Plant

AF-101 Common Stack (BLR-1342)

As listed in question II.B.3.a6

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
AF-101 Inorganic HAP 3-15-16-05

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yyyy) 3/15/2005 3/15/2005 3/16/2005

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 323.57 314.57 322.39 1000 lb steam/hr Common Stack for AF-101A and AF-101B

Total Heat Input (mmBtu/hr) 356.6 352 361 mmBtu/hr

Coal: Bituminous 356.6 352 361 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Hydrogen Chloride (HCl) 0.078 0.087 0.065 lb/mmBtu Method 26A

Hydrogen Flouride (HF) (select emission rate units)

Chlorine (Cl2) 0.0055 0.0072 0.0012 lb/mmBtu Method 26A

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 5 6 7

Exhaust Flowrate 126,527 124,895 128,104 dscfm

Exhaust Temperature 247 245 242 F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

DuPont Titanium Technologies - DeLisle Plant

AF-101 Common Stack (BLR-1342)

As listed in question II.B.3.a6
AF-101A PM and Metals 3-13-07

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/13/2007 3/13/2007 3/13/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 179.2 168.5 179.8 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 169.1 194.9 184.5 mmBtu/hr Exit Coal Boiler #1 ESP (AF-101A)

Coal: Bituminous 179.2 168.5 179.8 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.028 0.025 0.046 lb/mmBtu Methods 1-5; Test date after ESP DDDDD upgrade Third run included sootblowing 

period.

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 8 11 10

Exhaust Flowrate 74,194 72,301 75,497 dscfm

Exhaust Temperature 294 297 293 F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

DuPont Titanium Technologies - DeLisle Plant

AF-101A (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
AF-101B PM and Metals 7-19-07

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 7/19/2007 7/19/2007 7/19/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 191.3 188.3 185.7 1000 lb steam/hr

Total Heat Input (mmBtu/hr) 204.6 201.6 198.4 mmBtu/hr Exit Coal Boiler #2 ESP (AF-101B)

Coal: Bituminous 204.6 201.6 198.4 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.017 0.014 0.03 lb/mmBtu Methods 1-5; Test date after ESP DDDDD upgrade Third run included sootblowing 

period.

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 9 9 12

Exhaust Flowrate 69,118 67,908 58,209 dscfm

Exhaust Temperature 277 277 281 F

DuPont Titanium Technologies - DeLisle Plant

AF-101B (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
AF-101 PM and Metals 10-4-07

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 10/4/2007 10/4/2007 10/4/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 320.21 307.59 307.95 (select heat output units) Common Stack for AF-101A and AF-101B

Total Heat Input (mmBtu/hr) 356.59 342.53 342.93 mmBtu/hr

Coal: Bituminous 356.59 342.53 342.93 (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) (select emission rate units)

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.0138 0.0227 0.0542 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 10 10 10

Exhaust Flowrate 99,979 102,447 102,562 dscfm

Exhaust Temperature 302 307 306 F

DuPont Titanium Technologies - DeLisle Plant

AF-101 Common Stack (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
AF-103 PM and Metals 3-19-07

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/19/2007 3/19/2007 3/19/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 156.3 156.16 156.81 (select heat output units)

Total Heat Input (mmBtu/hr) 182.9 183 183.2 mmBtu/hr

Natural gas 182.9 183 183.2 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.00246 0.000929 0.000655 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 16 16 17

Exhaust Flowrate 42,914 41,632 41,698 dscfm

Exhaust Temperature 447 447 447 F

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

DuPont Titanium Technologies - DeLisle Plant

AF-103 (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
AH-101 PM and Metals 3-14-08

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/14/2008 3/14/2008 3/14/2008

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) (select heat output units)

Total Heat Input (mmBtu/hr) 19.22 19.27 19.37 mmBtu/hr

Natural gas 19.22 19.27 19.37 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.000572 0.000415 0.000361 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 16 14 16

Exhaust Flowrate 3,040 2,442 2,842 dscfm

Exhaust Temperature 1096 1097 1098 F, no economizer

DuPont Titanium Technologies - DeLisle Plant

AH-101 (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
AH-201 PM and Metals 3-10-08

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/10/2008 3/10/2008 3/10/2008

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) (select heat output units)

Total Heat Input (mmBtu/hr) 16.07 23.44 23.49 mmBtu/hr

Natural gas 16.07 23.44 23.49 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.002614 0.001237 0.000213 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 17 18 17

Exhaust Flowrate 2,680 3,907 4,226 dscfm

Exhaust Temperature 409 682 736 F, with economizer

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.

DuPont Titanium Technologies - DeLisle Plant

AH-201 (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)
AH-202 PM and Metals 3-29-07

Facility Name:

Combustor ID:

Control Device Configuration: 

Parameter

Sample #1Sample #2Sample #3

Test Average

Units

Units Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 3/29/2007 3/29/2007 3/29/2007

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) (select heat output units)

Total Heat Input (mmBtu/hr) 12.75 12.75 12.77 mmBtu/hr

Natural gas 12.75 12.75 12.77 mmBtu/hr

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Mercury (Hg) lb/mmBtu

Arsenic (As) (select emission rate units)

Beryllium (Be) (select emission rate units)

Cadmium (Cd) (select emission rate units)

Chromium (Cr) (select emission rate units)

Lead (Pb) (select emission rate units)

Manganese (Mn) (select emission rate units)

Nickel (Ni) (select emission rate units)

Selenium (Se) (select emission rate units)

Particulate Matter (front half) 0.000376 0.000227 0.000345 lb/mmBtu Methods 1-5

Particulate Matter (total, including condensibles) lb/mmBtu

Other Operating Parameters During Test (These parameters are only required if emission units are provided in units of concentration)

Dry or Wet Basis Dry Dry Dry Wet or Dry

Exhaust Stream %Moisture 12 12 12

Exhaust Flowrate 2,632 2,650 2,647 dscfm

Exhaust Temperature 740 737 738 F

DuPont Titanium Technologies - DeLisle Plant

AH-202 (BLR-1342)

As listed in question II.B.3.a1

(you may enter control device as listed in questions II.B.3.a1 or II.B.3.a6, or other (with description), if the 

control device during the test was not listed in the survey section II.B.3)

Enter numerical value when available. If 

the test results are below detection limit, 

please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
Attachment 4
From: Amanda Singleton

To: combustionsurvey

Date: 4/7/2010 6:42 PM

Subject: Fwd: Update to MACT survey

Attachments: Non-ERT HG Spreadsheet DataEntry FW boiler xls.xls

>>> "Michael Dalton" <MDALTON@amalsugar.com> 4/7/2010 6:32 PM >>>

Dear Mr. Eddinger and Ms. Singleton:

It has been brought to our attention that Mercury emissions reported in the MACT survey data sheets 

submitted as a result of your office's enquiry may not have been performed according to the EPA 

endorsed protocol for data reduction under Method 29.

The Amalgamated Sugar Company LLC has reviewed the data and after review with our stack testing 

consultants, believes the following file accurately represents mercury emissions and conforms to Method 

29 relative to the detection levels for the five test method fractions.

If you have any questions, please contact Bob Braun or myself.
Facility ID:

Combustor ID:

Control Device Configuration: 

Parameter

Sa

mple #1

Sa

mple #2

Sa

mple #3

Test Average

Units

U

nits Other 

Description

Test Method Used Test Location Note

Select appropriate unit from 

list. If other is selected please 

describe units in column H at 

right.

Enter the name of the Test Method used.

For Fuel input rates, enter the method used to determine 

the fuel input (e.g., F-factor, gas fuel meter, boiler 

efficiency calculation)

Indicate whether the test 

occurred upstream or 

downstream of a control 

device(s)

For all pollutants, provide any other 

information supporting information you 

think is necessary about this test report. 

Sample Date (mm/dd/yy) 9/26/06 9/26/06 9/27/06

Required Operating Parameters During Test

Steam Output (1000 lb/hr) (for boilers only) 174 173 169 1000 lb steam/hr Upstream

Total Heat Input (mmBtu/hr) 247.7 245.4 240.8 mmBtu/hr Upstream

Coal: Sub-bituminous 20220 20033 19657 lb/hour Boiler Efficiency Calculation

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

(select fuel type) (select fuel input units)

If other fuel type is selected please specify in this cell

Emission Data

Antimony (Sb) lb/mmBtu

Arsenic (As) lb/mmBtu

Beryllium (Be) lb/mmBtu

Cadmium (Cd) lb/mmBtu

Chromium (Cr) lb/mmBtu

Cobalt (Co) lb/mmBtu

Lead (Pb) lb/mmBtu

Manganese (Mn) lb/mmBtu

Mercury (Hg) [<2.562E-7] [<2.804E-7] [<2.915E-7] 2.76E-07 lb/mmBtu Method 29 Downstream Run 1 - DLL. Fractions 1B, 3A 

and 3C are BDL.

Run 2 - DLL. Fractions 1B, 3A, 3B 

and 3C are BDL.

Run 3 - DLL. Fractions 1B, 3A 

and 3C are BDL.

Average - DLL. Run 1, 2 and 3 

contain BDL fractions.

Nickel (Ni) lb/mmBtu

Phosphorus (P) lb/mmBtu

Selenium (Se) lb/mmBtu

Other Operating Parameters During Test

Exhaust Stream %Moisture %

Exhaust Stream % CO2 or O2 (sel exhaust O2/CO2 level)

Exhaust Flowrate (select flowrate units)

Exhaust Temperature (select temperature units)

The Amalgamated Sugar Company LLC

Foster Wheeler Boiler (S-B1)

Fabric Filter

Enter numerical value when available. If the test results are below 

detection limit, please note the detection limit in brackets 

(e.g., [< 0.010]). 

Select the fuel types used during emission test from the drop down menus and enter their corresponding fuel input rates below. You may enter up to 15 fuel types fired during the test.
Attachment 5
From: "Paul, Jeremy" <Jeremy_Paul@golder.com>

To: "eddinger.jim@epa.gov" <eddinger.jim@epa.gov>, Amanda Singleton 

<Amanda.Singleton@erg.com>, combustionsurvey <combustionsurvey@erg.com>

CC: "Buff, Dave" <DBuff@GOLDER.com>, "Bill_Tarr@floridacrystals.com" 

<Bill_Tarr@floridacrystals.com>, "cooper@mail.ucf.edu" <cooper@mail.ucf.edu>, "David Dee 

(ddee@yvlaw.net)" <ddee@yvlaw.net>, "Hector_Cardentey@floridacrystals.com" 

<Hector_Cardentey@floridacrystals.com>, "jfalvarez@scgc.org" <jfalvarez@scgc.org>, 

"John_Fanjul@floridacrystals.com" <John_Fanjul@floridacrystals.com>, "kdlockhart@scgc.org" 

<kdlockhart@scgc.org>, Keith Tingberg <ktingberg@ussugar.com>, "Matt 

Capone(matthew_capone@floridacrystals.com)" <matthew_capone@floridacrystals.com>, "O'Keefe, 

Sean at HCS" <sokeefe@hcsugar.com>, "Peter Briggs(pbriggs@ussugar.com)" <pbriggs@ussugar.com>

Date: 4/8/2010 11:00 AM

Subject: Sugar Industry VOC and THC Data for Boiler MACT Database

Attachments: Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10.xls

At the request of the Florida Sugar Industry, Golder Associates Inc. is submitting the attached boiler VOC 

and total hydrocarbon emissions data for inclusion in the Boiler MACT database. The attached file 

includes emissions data for boilers operated by Osceola Farms Company, United States Sugar 

Corporation, Sugar Cane Growers Cooperative of Florida, and Hawaiian Commercial & Sugar Company. 

This data was included in the MACT Floor Analysis for Bagasse-Fired Boilers report submitted to the U.S. 

EPA in June of 2009. To facilitate inclusion in the Boiler MACT database developed by ERG, the data is 

being submitted in an electronic format.

Please let us know if you have any questions.

Thank you,

Jeremy

________________________________

Jeremy D. Paul, E.I. | Staff Engineer | Golder Associates Inc.

6026 NW 1st Place, Gainesville, Florida, USA 32607

T: +1 (352) 336-5600 | F: +1 (352) 336-6603 | E: 

Jeremy_Paul@golder.com<mailto:Jeremy_Paul@golder.com> | 

www.golder.com<http://www.golder.com/>

Work Safe, Home Safe

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Accordingly, the electronic media version of any work product may not be relied upon.

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Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - U.S. Sugar Corporation - Clewiston

Boiler MACT Database Facility ID: FLUSSugarCorp

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

Boiler No. 1 Suspension 01/27/00 134,045 190,722 168,529 347.10 48.21 92 0.266 Carbon 92 0.266

Boiler No. 1 Suspension 01/27/00 134,626 191,880 165,195 339.46 47.15 243 0.716 Carbon 243 0.716

Boiler No. 1 Suspension 01/27/00 134,306 194,236 166,154 341.61 47.45 213 0.623 Carbon 213 0.623

Number of Runs 3 3 3 3 3 3 3 3 3

n-1 Degrees of Freedom (ν) 2 2 2 2 2 2 2 2 2

MEAN 134,326 192,279 166,626 342.72 47.60 183 0.535 183 0.535

MINIMUM 134,045 190,722 165,195 339.46 47.15 92 0.266 92 0.266

MAXIMUM 134,626 194,236 168,529 347.10 48.21 243 0.716 243 0.716

STD DEVIATION 291 1,791 1,716 3.94 0.55 80 0.238 80 0.238

95% CL OF RUNS 134,908 195,861 170,059 350.60 48.69 342 1.010 342 1.010

UPL (99% CONFIDENCE) 135,980 202,462 176,386 365.1 50.71 637 1.886 637 1.886

Boiler No. 2 Suspension 03/01/99 109,797 166,465 155,077 326.76 45.38 249 0.763 As Carbon 249 0.763

Boiler No. 2 Suspension 03/01/99 105,499 166,864 155,077 327.13 45.43 840 2.568 As Carbon 840 2.568

Boiler No. 2 Suspension 03/01/99 106,963 166,200 159,048 335.27 46.57 623 1.858 As Carbon 623 1.858

Boiler No. 2 Suspension 01/28/00 129,165 186,433 160,286 326.48 45.34 526 1.612 As Carbon 526 1.612

Boiler No. 2 Suspension 01/28/00 126,221 185,037 155,000 315.46 43.81 625 1.982 As Carbon 625 1.982

Boiler No. 2 Suspension 01/28/00 123,360 183,675 154,688 314.89 43.73 1021 3.241 As Carbon 1021 3.241

Number of Runs 6 6 6 6 6 6 6 6 6

n-1 Degrees of Freedom (ν) 5 5 5 5 5 5 5 5 5

MEAN 116,834 175,779 156,529 324.33 45 647 2.004 647 2.004

MINIMUM 105,499 166,200 154,688 314.89 44 249 0.763 249 0.763

MAXIMUM 129,165 186,433 160,286 335.27 47 1,021 3.241 1,021 3.241

STD DEVIATION 10,566 10,194 2,466 7.82 1 265 0.844 265 0.844

95% CL OF RUNS 137,966 196,166 161,461 339.97 47 1,177 3.693 1,177 3.693

UPL (99% CONFIDENCE) 141,974 200,033 162,397 342.94 48 1,277 4.013 1,277 4.013

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLUSSugarCorp 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - U.S. Sugar Corporation - Clewiston

Boiler MACT Database Facility ID: FLUSSugarCorp

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler No. 4 Suspension 01/05/00 136,759 238,378 509.00 70.7 144 0.282 As Carbon 143.65 0.282 204 As Propane 335 156.5 0.308 50.46 As Methane 12.90 0.025 10.0 92

Boiler No. 4 Suspension 01/05/00 136,322 241,644 514.50 71.5 490 0.952 As Carbon 490 0.952 834 As Propane 1254 637.8 1.240 581.74 As Methane 148.23 0.288 9.0 76

Boiler No. 4 Suspension 01/05/00 135,432 236,800 504.80 70.1 375 0.742 As Carbon 375 0.742 645 As Propane 990 490.1 0.971 456.35 As Methane 115.52 0.229 9.3 79

Boiler No. 4 Suspension 11/17/00 161,372 258,400 558.20 77.5 186 0.333 As Propane 152 0.272 236 As Propane 370 213.4 0.382 203.64 As Methane 61.42 0.110 9.5 83

Boiler No. 4 Suspension 11/17/00 160,074 256,667 554.70 77.0 121 0.219 As Propane 99 0.179 149 As Propane 238 134.0 0.242 116.69 As Methane 34.91 0.063 9.7 86

Boiler No. 4 Suspension 11/17/00 161,936 262,192 566.90 78.7 214 0.378 As Propane 175 0.309 245 As Propane 391 222.8 0.393 157.21 As Methane 47.58 0.084 9.7 86

Boiler No. 4 Suspension 01/23/02 158,108 255,882 549.83 76.4 15 0.028 As Propane 12 0.023 31 As Propane 56 27.4 0.050 50.59 As Methane 14.95 0.027 11.1 113

Boiler No. 4 Suspension 01/23/02 151,705 257,647 555.59 77.2 14 0.025 As Propane 11 0.020 30 As Propane 52 25.4 0.046 49.06 As Methane 13.91 0.025 10.7 105

Boiler No. 4 Suspension 01/23/02 155,993 260,294 561.30 78.0 20 0.035 As Propane 16 0.029 40 As Propane 70 34.6 0.062 63.39 As Methane 18.48 0.033 10.8 107

Boiler No. 4 Suspension 12/18/02 167,367 272,000 600.42 83.4 106 0.177 As Carbon 106 0.177 176 As Propane 305 165.6 0.276 190.28 As Methane 59.53 0.099 10.6 102

Boiler No. 4 Suspension 12/18/02 164,949 272,000 599.88 83.3 130 0.217 As Carbon 130 0.217 264 As Propane 437 244.6 0.408 370.53 As Methane 114.24 0.190 10.1 93

Boiler No. 4 Suspension 12/18/02 161,294 274,783 601.71 83.6 76 0.126 As Carbon 76 0.126 172 As Propane 285 155.5 0.258 265.37 As Methane 80.00 0.133 10.1 94

Boiler No. 4 Suspension 12/19/02 163,340 284,250 627.36 87.1 31 0.049 As Carbon 31 0.049 62 As Propane 106 56.9 0.091 85.16 As Methane 26.00 0.041 10.4 100

Boiler No. 4 Suspension 11/21/03 184,631 265,479 579.88 80.5 306 0.528 As Propane 250 0.431 387 As Propane 614 400.7 0.691 436.08 As Methane 150.49 0.260 9.6 86

Boiler No. 4 Suspension 11/21/03 187,732 264,167 576.87 80.1 257 0.445 As Propane 210 0.364 366 As Propane 571 385.7 0.669 500.94 As Methane 175.78 0.305 9.4 82

Boiler No. 4 Suspension 11/21/03 179,768 260,000 567.11 78.8 202 0.356 As Propane 165 0.291 194 As Propane 327 195.4 0.345 90.64 As Methane 30.45 0.054 10.3 97

Boiler No. 4 Suspension 11/24/04 164,581 254,686 267,115 588.49 81.7 187 0.318 As Propane 153 0.260 188 As Propane 300 173.6 0.295 67.79 As Methane 20.85 0.035 9.7 87

Boiler No. 4 Suspension 11/24/04 165,619 262,011 259,737 572.19 79.5 335 0.585 As Propane 273 0.478 419 As Propane 654 389.5 0.681 374.91 As Methane 116.06 0.203 9.4 82

Boiler No. 4 Suspension 01/13/06 127,859 203,260 229,014 478.30 66.4 47 0.098 As Propane 38 0.080 90 As Propane 131 64.6 0.135 110.26 As Methane 26.35 0.055 8.7 71

Boiler No. 4 Suspension 01/13/06 123,326 198,482 244,225 510.40 70.9 55 0.108 As Propane 45 0.088 118 As Propane 162 81.9 0.160 160.32 As Methane 36.96 0.072 7.8 60

Boiler No. 4 Suspension 01/13/06 122,129 196,063 236,522 498.00 69.2 22 0.043 As Propane 18 0.035 56 As Propane 78 38.2 0.077 90.12 As Methane 20.57 0.041 8.2 64

Boiler No. 4 Suspension 12/01/06 153,199 228,528 242,466 532.08 73.9 217 0.408 As Propane 178 0.333 317 As Propane 510 272.3 0.512 330.90 As Methane 94.75 0.178 9.8 88

Boiler No. 4 Suspension 12/01/06 151,842 225,833 245,070 519.67 72.2 65 0.125 As Propane 53 0.102 99 As Propane 169 84.1 0.162 109.27 As Methane 31.01 0.060 10.5 100

Boiler No. 4 Suspension 12/01/06 146,862 225,359 255,000 554.18 77.0 51 0.093 As Propane 42 0.076 87 As Propane 139 71.9 0.130 109.22 As Methane 29.98 0.054 9.7 86

Boiler No. 4 Suspension 11/14/07 148,008 226,867 271,454 579.59 80.5 117 0.203 As Propane 96 0.166 143 As Propane 215 118.4 0.204 81.00 As Methane 22.41 0.039 9.1 76

Boiler No. 4 Suspension 11/14/07 158,968 237,835 271,923 579.23 80.4 99 0.172 As Propane 81 0.141 141 As Propane 210 126.0 0.218 150.74 As Methane 44.79 0.077 8.9 73

Boiler No. 4 Suspension 11/14/07 156,081 234,579 265,600 567.96 78.9 43 0.076 As Propane 35 0.062 66 As Propane 99 57.7 0.102 76.29 As Methane 22.26 0.039 9.1 76

Boiler No. 4 Suspension 12/08/08 155,783 241,570 265,735 554.03 76.9 51 0.093 As Propane 42 0.076 48 As Propane 79 42.2 0.076 1.08 As Methane 0.32 0.001 10.0 92

Boiler No. 4 Suspension 12/08/08 159,113 242,063 264,429 550.78 76.5 31 0.056 As Propane 25 0.046 28 As Propane 45 25.1 0.046 0.10 As Methane 0.03 0.000 9.8 88

Boiler No. 4 Suspension 12/08/08 159,904 238,705 273,409 567.55 78.8 23 0.041 As Propane 19 0.034 21 As Propane 35 18.9 0.033 0.09 As Methane 0.03 0.000 10.3 97

Boiler No. 4 Suspension 11/18/09 138,974 220,345 262,059 559.32 77.7 22 0.039 As Propane 18 0.032 17 As Propane 25 17.9 0.032 8.9 74

Boiler No. 4 Suspension 11/18/09 137,572 216,245 263,283 558.62 77.6 1.2 0.002 As Propane 0.94 0.002 0.90 As Propane 1.4 0.9 0.002 9.5 83

Boiler No. 4 Suspension 11/18/09 139,114 216,646 260,870 553.65 76.9 7.4 0.013 As Propane 6.07 0.011 5.8 As Propane 8.7 6.1 0.011 9.0 76

Number of Runs 33 17 33 33 33 33 33 33 33 33 33 33 33 30 30 30 33 33

n-1 Degrees of Freedom (ν) 32 16 32 32 32 32 32 32 32 32 32 32 32 29 29 29 32 32

MEAN 153,810 227,593 258,742 556.12 77.24 123 0.223 108 0.196 178 281 155.6 0.282 177.67 52.36 0.094 9.7 87

MINIMUM 122,129 196,063 229,014 478.30 66.43 1.15 0.002 0.94 0.002 0.90 1.4 0.9 0.002 0.09 0.03 0.000 7.8 60

MAXIMUM 187,732 262,011 284,250 627.36 87.13 490 0.952 490 0.952 834 1,254 637.8 1.240 581.74 175.78 0.305 11.1 113

STD DEVIATION 15,912 18,277 12,981 33.11 4.60 121 0.227 113 0.214 186 285 154.8 0.290 160.93 49.00 0.088 0.8 12

95% CL OF RUNS 185,634 264,147 284,705 622.34 86.44 365 0.677 333 0.624 550 850 465.3 0.862 499.54 150.36 0.270 11.2 112

UPL (99% CONFIDENCE) 177,306 257,162 277,911 605.0 84.03 302 0.558 274 0.512 453 701 384.2 0.710 417.60 125.410 0.2 10.83 106

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLUSSugarCorp 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - U.S. Sugar Corporation - Clewiston

Boiler MACT Database Facility ID: FLUSSugarCorp

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler No. 7 Suspension 11/17/97 157,787 349,315 734.00 101.94 8.3 0.011 As Carbon 8.3 0.011 9.4 As Propane 12 8.3 0.011 0.004 As Methane 0.001 1.8E-06 6.56 46

Boiler No. 7 Suspension 11/17/97 163,257 343,200 714.00 99.17 7.8 0.011 As Carbon 7.8 0.011 8.5 As Propane 11 7.8 0.011 0.003 As Methane 0.001 1.4E-06 6.87 49

Boiler No. 7 Suspension 11/17/97 153,899 352,603 735.00 102.08 5.0 0.007 As Carbon 5.0 0.007 5.8 As Propane 7.1 5.0 0.007 0.005 As Methane 0.001 1.8E-06 6.45 45

Boiler No. 7 Suspension 02/08/99 176,423 362,368 741.30 102.96 1.2 0.002 As Carbon 1.2 0.002 1.4 As Propane 1.8 1.3 0.002 0.50 As Methane 0.166 0.0002 7.50 56

Boiler No. 7 Suspension 12/17/99 134,535 369,429 763.08 105.98 21 0.028 As Carbon 21 0.028 28 As Propane 29 21.3 0.028 0.05 As Methane 0.012 1.6E-05 3.60 21

Boiler No. 7 Suspension 12/17/99 134,831 357,429 736.74 102.33 2.7 0.004 As Carbon 2.7 0.004 3.5 As Propane 3.9 2.6 0.004 0.00 As Methane 0.000 0.000 4.80 30

Boiler No. 7 Suspension 12/17/99 136,090 366,176 755.14 104.88 4.5 0.006 As Carbon 4.5 0.006 5.9 As Propane 6.6 4.5 0.006 0.01 As Methane 0.004 4.8E-06 4.90 31

Boiler No. 7 Suspension 01/05/01 179,424 327,500 655.88 91.09 0.70 0.001 As Carbon 0.70 0.001 0.70 As Propane 1.1 0.7 0.001 0.01 As Methane 0.005 6.9E-06 9.08 77

Boiler No. 7 Suspension 01/05/01 174,762 326,667 667.68 92.73 0.57 0.001 As Carbon 0.57 0.001 0.58 As Propane 0.87 0.6 0.001 0.00 As Methane 0.000 0.000 8.98 75

Boiler No. 7 Suspension 01/06/01 172,827 328,333 675.11 93.77 0.83 0.001 As Carbon 0.83 0.001 0.86 As Propane 1.29 0.8 0.001 0.01 As Methane 0.004 5.6E-06 8.95 75

Boiler No. 7 Suspension 01/09/02 130,764 324,545 691.41 96.03 25 0.036 As Carbon 25 0.036 38 As Propane 48 27.9 0.040 12.05 As Methane 2.944 0.004 6.67 47

Boiler No. 7 Suspension 01/09/02 136,455 331,714 706.88 98.18 76 0.107 As Carbon 76 0.107 103 As Propane 128 79.1 0.112 13.29 As Methane 3.389 0.005 6.43 44

Boiler No. 7 Suspension 01/09/02 140,707 333,429 708.68 98.43 142 0.200 As Carbon 142 0.200 190 As Propane 235 150.2 0.212 32.53 As Methane 8.556 0.012 6.41 44

Boiler No. 7 Suspension 11/15/02 148,856 363,659 772.94 107.35 6.6 0.009 As Carbon 6.6 0.009 13 As Propane 17 11.1 0.014 16.01 As Methane 4.454 0.006 6.56 46

Boiler No. 7 Suspension 11/15/02 155,948 343,200 727.96 101.11 5.1 0.007 As Carbon 5.1 0.007 6.9 As Propane 9.3 6.0 0.008 3.22 As Methane 0.940 0.001 7.65 58

Boiler No. 7 Suspension 11/15/02 150,966 334,737 709.05 98.48 4.5 0.006 As Carbon 4.5 0.006 6.6 As Propane 9.2 5.6 0.008 4.02 As Methane 1.135 0.002 7.96 61

Boiler No. 7 Suspension 12/30/03 144,480 287,753 354,783 744.67 103.43 47.4 0.064 As Carbon 47.4 0.064 59 As Propane 72 47.5 0.064 0.15 As Methane 0.040 5.3E-05 6.36 44

Boiler No. 7 Suspension 12/30/03 148,005 283,321 329,250 688.40 95.61 18.1 0.026 As Carbon 18.1 0.026 22 As Propane 28 18.1 0.026 0.06 As Methane 0.018 2.6E-05 6.99 50

Boiler No. 7 Suspension 12/30/03 145,898 281,972 338,630 707.48 98.26 12.7 0.018 As Carbon 12.7 0.018 16 As Propane 19 12.7 0.018 0.04 As Methane 0.012 1.7E-05 6.58 46

Boiler No. 7 Suspension 02/04/05 165,392 296,331 232,174 494.28 68.65 4.1 0.008 As Carbon 4.1 0.008 4.4 As Propane 7.8 4.12 0.008 0.00 As Methane 0.000 0.000 10.72 105

Boiler No. 7 Suspension 02/04/05 161,579 296,174 228,000 487.84 67.76 4.4 0.009 As Carbon 4.4 0.009 4.9 As Propane 8.7 4.4 0.009 0.004 As Methane 0.001 2.7E-06 10.80 107

Boiler No. 7 Suspension 02/04/05 159,426 285,860 223,099 475.52 66.04 0.89 0.002 As Carbon 0.89 0.002 1.0 As Propane 1.9 0.9 0.002 0.01 As Methane 0.004 9.1E-06 11.28 117

Boiler No. 7 Suspension 01/05/06 184,525 318,378 318,300 659.80 91.64 3.7 0.006 As Carbon 3.7 0.006 3.6 As Propane 6 3.7 0.006 0.0E+00 9.78 88

Boiler No. 7 Suspension 01/05/06 178,105 315,125 348,674 721.50 100.21 11 0.015 As Carbon 11 0.015 11 As Propane 16 11.0 0.015 0.0E+00 8.80 73

Boiler No. 7 Suspension 01/05/06 173,265 306,013 349,209 720.60 100.08 2.3 0.003 As Carbon 2.3 0.003 2.4 As Propane 3 2.3 0.003 0.0E+00 8.76 72

Boiler No. 7 Suspension 01/25/07 185,288 318,417 307,597 637.19 88.50 2.2 0.004 As Carbon 2.2 0.004 2.2 As Propane 3.7 2.2 0.004 0.01 As Methane 0.005 7.4E-06 10.56 102

Boiler No. 7 Suspension 01/25/07 174,015 301,630 319,097 658.39 91.44 0.63 0.001 As Carbon 0.63 0.001 0.65 As Propane 1.0 0.6 0.001 0.01 As Methane 0.005 6.8E-06 9.78 88

Boiler No. 7 Suspension 01/25/07 175,714 301,314 290,569 599.18 83.22 0.44 0.001 As Carbon 0.44 0.001 0.45 As Propane 0.79 0.4 0.001 0.01 As Methane 0.004 5.9E-06 10.71 105

Boiler No. 7 Suspension 01/24/08 157,003 289,313 337,192 712.98 99.03 0.04 0.00005 As Carbon 0.04 0.00005 0.04 As Propane 0.05 0.04 0.00005 7.18 52

Boiler No. 7 Suspension 01/24/08 154,128 285,290 361,014 758.13 105.30 0.91 0.001 As Carbon 0.91 0.001 1.1 As Propane 1.3 0.9 0.001 6.77 48

Boiler No. 7 Suspension 01/24/08 158,129 287,635 344,968 724.38 100.61 3.5 0.005 As Carbon 3.5 0.005 3.9 As Propane 5.0 3.5 0.005 6.84 49

Boiler No. 7 Suspension 12/04/08 181,705 333,116 370,870 731.80 101.64 0.020 2.78E-05 As Carbon 0.020 0.000 0.02 As Propane 0.03 0.0 0.000 10.00 92

Boiler No. 7 Suspension 12/05/08 183,193 326,584 361,846 705.00 97.92 0.58 8.16E-04 As Carbon 0.58 0.001 0.56 As Propane 0.90 0.6 0.001 9.83 89

Boiler No. 7 Suspension 11/20/09 201,024 368,568 345,455 719.78 99.97 2.47 0.003 As Propane 2.02 0.002 1.4 As Propane 2.4 1.6 0.002 10.30 97

Boiler No. 7 Suspension 11/20/09 202,860 372,427 351,692 734.21 101.97 3.57 0.005 As Propane 2.92 0.004 2.0 As Propane 3.2 2.3 0.003 9.90 90

Boiler No. 7 Suspension 11/20/09 204,353 374,421 337,273 702.63 97.59 12 0.017 As Propane 9.50 0.014 6.5 As Propane 11 7.5 0.011 10.20 95

Number of Runs 36 20 36 36 36 36 36 36 36 36 36 36 36 25 25 28 36 36

n-1 Degrees of Freedom (ν) 35 19 35 35 35 35 35 35 35 35 35 35 35 24 24 27 35 35

MEAN 163,489 311,482 332,333 691.07 95.98 12.27 0.017 12.18 0.017 16 20 12.7 0.018 3.28 0.868 0.001 8.10 67

MINIMUM 130,764 281,972 223,099 475.52 66.04 0.02 0.000 0.02 0.000 0.02 0.03 0.0 0.000 0.001 0.0001 0.000 3.60 21

MAXIMUM 204,353 374,421 370,870 772.94 107.35 141.65 0.200 141.65 0.200 190 235 150.2 0.212 32.53 8.556 0.012 11.28 117

STD DEVIATION 19,891 29,968 36,538 72.66 10.09 26.63 0.037 26.64 0.037 36 44 28.1 0.040 7.62 2.006 0.003 1.96 26

95% CL OF RUNS 203,271 371,418 405,409 836.39 116.17 65.53 0.092 65.47 0.092 88 108 68.9 0.097 18.52 4.880 0.006 12.02 118

UPL (99% CONFIDENCE) 192,627 358,600 385,857 797.5 110.77 51.28 0.072 51.21 0.072 68 85 53.9 0.076 14.89 3.922 0.0 10.97 105

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLUSSugarCorp 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - U.S. Sugar Corporation - Clewiston

Boiler MACT Database Facility ID: FLUSSugarCorp

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler No. 8 Suspension 03/24/05 236,278 441,324 518,571 982.6 136.47 12 0.013 As Propane 10 0.011 7.7 As Propane 9.5 10.2 0.010 0.03 As Methane 0.011 1.2E-05 6.52 45

Boiler No. 8 Suspension 03/24/05 218,901 416,739 487,595 880.2 122.24 9.5 0.010 As Propane 7.75 0.008 6.3 As Propane 8.1 7.8 0.009 0.03 As Methane 0.014 1.6E-05 6.96 50

Boiler No. 8 Suspension 03/25/05 218,815 416,838 496,578 919.1 127.66 12 0.013 As Propane 10 0.011 8.2 As Propane 10 10.1 0.011 0.04 As Methane 0.018 1.9E-05 6.53 45

Boiler No. 8 Suspension 01/10/06 208,889 386,258 523,478 970.2 134.75 10 0.010 As Propane 8 0.008 13 As Propane 14 15.3 0.016 18.04 As Methane 7.044 0.007 4.73 29

Boiler No. 8 Suspension 01/10/06 222,090 393,669 521,408 967.6 134.39 14 0.014 As Propane 11 0.011 18 As Propane 20 22.3 0.023 26.05 As Methane 10.814 0.011 5.01 32

Boiler No. 8 Suspension 01/10/06 211,224 393,180 510,423 949.6 131.89 12 0.013 As Propane 10 0.011 17 As Propane 18 19.8 0.021 25.17 As Methane 9.938 0.010 4.66 29

Boiler No. 8 Suspension 01/05/07 237,896 406,875 499,726 919.5 127.71 41 0.045 As Propane 34 0.037 25 As Propane 34 33.6 0.037 0.09 As Methane 0.041 4.4E-05 7.73 59

Boiler No. 8 Suspension 01/05/07 236,384 429,330 520,274 960.3 133.38 19 0.020 As Propane 16 0.016 12 As Propane 16 15.9 0.017 0.05 As Methane 0.022 2.3E-05 7.65 58

Boiler No. 8 Suspension 01/05/07 229,933 443,786 510,811 948.0 131.67 27 0.029 As Propane 22 0.024 17 As Propane 23 22.3 0.024 0.07 As Methane 0.028 3.0E-05 7.25 53

Boiler No. 8 Suspension 11/29-30/07 227,945 448,255 526,093 968.3 134.48 3.7 0.004 As Propane 3.02 0.003 2.37 As Propane 2.9 3.0 0.003 0.02 As Methane 0.007 7.1E-06 6.14 42

Boiler No. 8 Suspension 11/29-30/07 228,148 434,556 532,977 980.8 136.22 7.3 0.007 As Propane 5.98 0.006 4.7 As Propane 5.6 6.0 0.006 0.02 As Methane 0.008 7.9E-06 5.84 39

Boiler No. 8 Suspension 11/29-30/07 247,952 467,497 540,786 999.6 138.83 7.3 0.007 As Propane 5.99 0.006 4.3 As Propane 5.6 6.0 0.006 0.01 As Methane 0.005 4.8E-06 7.21 53

Boiler No. 8 Suspension 11/29-30/07 241,314 469,578 575,771 1,061.9 147.48 15 0.015 As Propane 13 0.012 9.4 As Propane 12 12.7 0.012 0.03 As Methane 0.015 1.4E-05 6.70 47

Boiler No. 8 Suspension 11/29-30/07 247,207 474,721 545,768 1,011.6 140.49 20 0.020 As Propane 16 0.016 12 As Propane 15 16.3 0.016 0.04 As Methane 0.019 1.9E-05 6.73 47

Boiler No. 8 Suspension 11/29-30/07 248,621 476,866 575,034 1,063.3 147.68 41 0.039 As Propane 34 0.032 24 As Propane 30 33.7 0.032 0.09 As Methane 0.041 3.8E-05 6.60 46

Boiler No. 8 Suspension 01/30/09 238,331 441,283 530,642 980.1 136.12 17 0.018 As Propane 14 0.015 9.6 As Propane 13 14.1 0.015 7.70 58

Boiler No. 8 Suspension 01/30/09 242,761 443,818 504,742 922.3 128.10 97 0.105 As Propane 79 0.086 54 As Propane 91 79.3 0.086 10.40 99

Boiler No. 8 Suspension 01/30/09 249,681 452,303 531,158 984.3 136.70 0.41 0.000 As Propane 0.3 0.000 0.22 As Propane 0.26 0.3 0.000 5.80 38

Boiler No. 8 Suspension 12/03/09 188,050 404,792 506,957 929.4 129.08 8 0.009 As Propane 6.5 0.007 4.3 As Propane 5.3 6.5 0.007 6.40 44

Boiler No. 8 Suspension 12/03/09 198,746 408,895 485,625 891.7 123.84 23 0.026 As Propane 18.7 0.021 12 As Propane 15 18.7 0.021 6.60 46

Boiler No. 8 Suspension 12/04/09 271,433 525,283 963.7 133.84 16 0.016 As Propane 12.7 0.013 6.2 As Propane 5.3 12.7 0.013

Number of Runs 21 20 21 21 21 18 21 21 21 21 21 21 21 15 15 15 20 20

n-1 Degrees of Freedom (ν) 20 19 20 20 20 17 20 20 20 20 20 20 20 14 14 14 19 19

MEAN 230,981 432,528 522,367 964.5 133.95 19.71 0.021 16.11 0.017 13 17 18.2 0.018 4.65 1.868 0.002 6.66 48

MINIMUM 188,050 386,258 485,625 880.2 122.24 0.41 0.000 0.34 0.000 0.22 0.26 0.3 0.000 0.01 0.005 0.000 4.66 29

MAXIMUM 271,433 476,866 575,771 1,063.3 147.68 97.05 0.105 79.31 0.086 54 91 79.3 0.086 26.05 10.814 0.011 10.40 99

STD DEVIATION 19,242 28,175 23,849 46.9 6.51 20.59 0.022 16.83 0.018 11 19 16.7 0.018 9.68 3.900 0.004 1.26 15

95% CL OF RUNS 269,465 488,879 570,064 1,058.3 146.98 60.89 0.065 49.76 0.053 36 55 51.6 0.054 24.02 9.669 0.010 9.18 78

UPL (99% CONFIDENCE) 261,004 476,828 559,578 1,037.6 144.12 52.67 0.055 42.36 0.045 31 47 44.3 0.046 20.73 8.342 0.0 8.64 71

Notes:

lb/hr = pounds per hour.

lb/MMBtu = pounds per million British thermal units.

lb/ton = pounds per ton.

MMBtu/hr = million British thermal units per hour.

TPH = tons per hour.

Footnotes:

1 Assumed 3,600 Btu/lb average heat content for wet bagasse, except where noted.

2 Based on actual reported data.

3

If reported as propane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as propane x ((3*12.011)/44.09) 

 where 44.09 is the MW of propane and 12.011 is the MW of carbon.

 If reported as methane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as methane x (12.011/16.04) 

 where 16.04 is the MW of methane and 12.011 is the MW of carbon.

4 As reported in test report.

5

If necessary, converted basis to as carbon.

6

25% Wood chip / 75% Bagasse

7

100% Bagasse

8 Wood chip firing at 4,500 Btu/lb. Data corresponding to wood chips was not used in any of the summary calculations.

9

50% Wood Chip / 50% Bagasse

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLUSSugarCorp 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

Boiler No. 1 Suspension 11/19/97 64,886 125,070 241.64 33.56 11 0.046 As Carbon 11 0.046 60 As propane 91 21.93 0.091 90.07 As Methane 10.92 0.045 9.02 75

Boiler No. 1 Suspension 11/19/97 68,452 126,957 245.20 34.06 3 0.012 As Carbon 3 0.012 41 As propane 62 15.92 0.065 102.03 As Methane 13.05 0.053 8.92 73

Boiler No. 1 Suspension 11/19/97 66,247 125,217 241.44 33.53 1 0.006 As Carbon 1 0.006 14 As propane 21 5.10 0.021 29.98 As Methane 3.71 0.015 9.27 79

Boiler No. 1 Suspension 11/18/98 65,314 123,478 241.32 33.52 16 0.067 As Carbon 16 0.067 149 As propane 224 54.41 0.225 313.71 As Methane 38.30 0.159 9.07 76

Boiler No. 1 Suspension 11/18/98 65,399 116,471 226.38 31.44 1 0.006 As Carbon 1 0.006 114 As propane 172 41.84 0.185 331.62 As Methane 40.54 0.179 9.07 76

Boiler No. 1 Suspension 11/18/98 58,801 120,000 232.67 32.32 0 0.002 As Carbon 0 0.002 296 As propane 404 97.73 0.420 885.36 As Methane 97.31 0.418 7.77 58

Boiler No. 1 Suspension 02/23/99 69,751 102,492 121,765 237.40 32.97 14 0.059 As Carbon 14 0.059

Boiler No. 1 Suspension 02/23/99 64,669 94,419 121,765 237.62 33.00 19 0.081 As Carbon 19 0.081

Boiler No. 1 Suspension 02/23/99 70,944 100,755 118,209 230.72 32.04 10 0.044 As Carbon 10 0.044

Boiler No. 1 Suspension 12/09/99 56,310 139,412 270.74 37.60 101 0.193 As Carbon 101 0.193 420 As propane 521 132.60 0.490 300.92 As Methane 31.67 0.117 6.48 44

Boiler No. 1 Suspension 12/09/99 61,472 141,176 274.47 38.12 107 0.216 As Carbon 107 0.216 404 As propane 507 139.19 0.507 280.84 As Methane 32.27 0.118 6.65 46

Boiler No. 1 Suspension 12/09/99 59,761 142,609 276.71 38.43 105 0.210 As Carbon 105 0.210 414 As propane 515 138.85 0.502 300.84 As Methane 33.60 0.121 6.50 45

Boiler No. 1 Suspension 11/15/00 73,772 120,000 232.18 32.25 11 0.046 As Carbon 11 0.046 46 As propane 73 18.85 0.081 60.12 As Methane 8.29 0.036 9.72 86

Boiler No. 1 Suspension 11/15/00 71,585 121,765 236.19 32.80 4 0.018 As Carbon 4 0.018 44 As propane 70 17.67 0.075 100.09 As Methane 13.39 0.057 9.61 84

Boiler No. 1 Suspension 11/15/00 71,101 120,870 234.79 32.61 0 0.001 As Carbon 0 0.001 26 As propane 41 10.45 0.044 78.59 As Methane 10.44 0.044 9.52 82

Boiler No. 1 Suspension 11/14/01 65,459 127,059 246.84 34.28 46 0.187 As Carbon 46 0.187 141 As propane 189 51.78 0.210 45.81 As Methane 5.61 0.023 7.57 56

Boiler No. 1 Suspension 11/14/01 65,301 115,833 224.78 31.22 13 0.059 As Carbon 13 0.059 36 As propane 52 13.30 0.059 0.06 As Methane 0.01 3.2E-05 8.36 66

Boiler No. 1 Suspension 11/14/01 65,000 111,045 215.18 29.89 11 0.049 As Carbon 11 0.049 29 As propane 43 10.54 0.049 0.15 As Methane 0.02 8.2E-05 8.94 74

Boiler No. 1 Suspension 11/13/02 63,791 123,409 239.39 33.25 5 0.023 As Carbon 5 0.023 16 As propane 23 5.66 0.024 2.08 As Methane 0.25 0.001 8.55 68

Boiler No. 1 Suspension 11/13/02 63,931 123,529 240.12 33.35 22 0.093 As Carbon 22 0.093 63 As propane 88 22.53 0.094 2.14 As Methane 0.26 0.001 8.20 64

Boiler No. 1 Suspension 11/13/02 66,452 126,957 247.13 34.32 16 0.065 As Carbon 16 0.065 77 As propane 104 28.69 0.116 101.14 As Methane 12.56 0.051 7.70 58

Boiler No. 1 Suspension 01/07/04 59,871 95,127 137,600 262.78 36.50 8 0.032 As Carbon 8 0.032 47 As propane 62 15.76 0.060 65.13 As Methane 7.29 0.028 7.27 53

Boiler No. 1 Suspension 01/07/04 58,919 96,206 140,833 268.80 37.33 18 0.066 As Carbon 18 0.066 102 As propane 124 33.70 0.125 145.22 As Methane 15.99 0.059 6.20 42

Boiler No. 1 Suspension 01/07/04 59,778 104,824 140,597 268.36 37.27 56 0.208 As Carbon 56 0.208 334 As propane 397 111.88 0.417 500.59 As Methane 55.93 0.208 5.88 39

Boiler No. 1 Suspension 12/15/04 63,484 109,438 132,537 249.24 34.62 15 0.061 As Carbon 15 0.061 43 As propane 59 15.21 0.061 0.14 As Methane 0.02 6.6E-05 7.85 59

Boiler No. 1 Suspension 12/15/04 63,706 113,864 130,541 245.30 34.07 16 0.066 As Carbon 16 0.066 45 As propane 64 16.11 0.066 0.11 As Methane 0.01 5.6E-05 8.31 65

Boiler No. 1 Suspension 12/15/04 70,287 119,463 132,353 249.00 34.58 20 0.080 As Carbon 20 0.080 51 As propane 72 19.93 0.080 0.08 As Methane 0.01 4.4E-05 8.35 66

Boiler No. 1 Suspension 01/13/06 53,423 88,199 144,000 275.90 38.32 17 0.060 As Methane 12 0.045 169 As methane 80 16.84 0.061 43.74 As Methane 4.37 0.016 8.30 65

Boiler No. 1 Suspension 01/13/06 55,826 92,043 149,000 284.60 39.53 30 0.104 As Methane 22 0.078 311 As methane 152 32.49 0.114 98.56 As Methane 10.28 0.036 8.71 70

Boiler No. 1 Suspension 01/13/06 54,255 89,559 149,000 283.10 39.32 26 0.092 As Methane 19 0.069 247 As methane 119 25.06 0.089 55.05 As Methane 5.58 0.020 8.48 67

Boiler No. 1 Suspension 12/08/06 75,691 113,263 126,000 234.80 32.61 1 0.004 As Carbon 1 0.004 2.0 As propane 3.3 0.86 0.004 0.01 As Methane 0.002 8.2E-06 9.77 86

Boiler No. 1 Suspension 12/08/06 72,313 109,579 131,471 245.20 34.06 0 0.001 As Carbon 0 0.001 0.47 As propane 0.72 0.19 0.001 0.005 As Methane 0.001 2.7E-06 9.20 78

Boiler No. 1 Suspension 12/08/06 69,611 109,868 127,941 238.60 33.14 0 0.001 As Carbon 0 0.001 0.73 As propane 1.1 0.29 0.001 0.04 As Methane 0.01 2.1E-05 9.50 82

Boiler No. 1 Suspension 12/12/07 60,851 95,708 124,811 233.37 32.41 1 0.004 As Carbon 1 0.004 6.7 As propane 10 2.27 0.010 11.64 As Methane 1.32 5.7E-03 9.05 75

Boiler No. 1 Suspension 12/12/07 67,749 102,810 131,865 247.62 34.39 2 0.008 As Carbon 2 0.008 6.7 As propane 9.7 2.55 0.010 3.74 As Methane 0.48 1.9E-03 8.47 67

Boiler No. 1 Suspension 12/12/07 63,746 101,578 135,652 254.58 35.36 3 0.012 As Carbon 3 0.012 11 As propane 16 4.07 0.016 8.18 As Methane 0.98 3.8E-03 8.07 62

Boiler No. 1 Suspension 01/07/09 64,513 100,301 140,000 268.11 37.24 8 0.029 As Carbon 8 0.029 22 As propane 33 7.90 0.029 0.00 As Methane 0.01 2.4E-05 8.90 73

Boiler No. 1 Suspension 01/07/09 64,543 102,663 140,426 269.31 37.40 66 0.245 As Carbon 66 0.245 182 As propane 264 65.94 0.245 0.00 As Methane 0.05 1.9E-04 8.55 68

Boiler No. 1 Suspension 01/08/09 62,487 98,553 141,882 271.74 37.74 11 0.041 As Carbon 11 0.041 32 As propane 47 11.20 0.041 0.00 As Methane 0.01 2.2E-05 8.80 72

Boiler No. 1 Suspension 01/08/09 60,301 105,897 135,882 260.20 36.14 9 0.035 As Carbon 9 0.035 27 As propane 43 9.16 0.035 0.00 As Methane 0.00 1.4E-05 9.54 83

Number of Runs 40 22 40 40 40 40 40 40 40 37 37 37 37 37 37 37 37 37

n-1 Degrees of Freedom (ν) 39 21 39 39 39 39 39 39 39 36 36 36 36 36 36 36 36 36

MEAN 64,494 102,119 130,125 249.59 34.67 20.64 0.066 20.18 0.064 109 128 32.93 0.128 106.97 12.29 0.049 8.38 67

MINIMUM 53,423 88,199 111,045 215.18 29.89 0.00 0.001 0.0010 0.001 0.47 0.72 0.19 0.001 0.000 0.001 2.7E-06 5.88 39

MAXIMUM 75,691 119,463 149,000 284.60 39.53 106.92 0.245 106.92 0.245 420 521 139.19 0.507 885.36 97.31 0.418 9.77 86

STD DEVIATION 5,258 8,195 9,647 17.64 2.45 28.16 0.068 28.13 0.068 128 151 40.02 0.149 180.37 20.15 0.083 1.03 13

95% CL OF RUNS 75,010 118,508 149,419 284.88 39.57 76.95 0.202 76.44 0.200 365 430 112.97 0.426 467.71 52.58 0.216 10.43 93

UPL (99% CONFIDENCE) 72,129 114,816 144,134 275.21 38.22 61.53 0.165 61.03 0.162 296 349 91.41 0.346 370.56 41.73 0.171 9.88 86

ppm @ 3% 

O2 as Propane

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 2 Suspension 11/20/97 68,217 123,429 238.62 33.14 44 0.186 As Carbon 44 0.186 214 As propane 333 82.0 0.344 295.39 As Methane 37.66 0.158 9.39 80

Boiler No. 2 Suspension 11/20/97 67,469 118,442 228.70 31.76 16 0.068 As Carbon 16 0.068 83 As propane 142 31.4 0.137 125.17 As Methane 15.79 0.069 10.45 98

Boiler No. 2 Suspension 11/20/97 69,974 125,455 241.92 33.60 8 0.033 As Carbon 8 0.033 85 As propane 127 33.4 0.138 195.87 As Methane 25.62 0.106 8.91 73

Boiler No. 2 Suspension 11/19/98 65,875 121,739 234.51 32.57 58 0.249 As Carbon 58 0.249 388 As propane 575 143.2 0.611 689.36 As Methane 84.88 0.362 8.84 72

Boiler No. 2 Suspension 11/19/98 63,498 136,901 263.72 36.63 9 0.035 As Carbon 9 0.035 296 As propane 395 105.4 0.400 810.86 As Methane 96.24 0.365 7.51 55

Boiler No. 2 Suspension 11/19/98 65,441 123,692 238.48 33.12 32 0.136 As Carbon 32 0.136 302 As propane 439 110.9 0.465 641.42 As Methane 78.46 0.329 8.60 69

Boiler No. 2 Suspension 12/08/99 67,341 118,783 229.70 31.90 41 0.180 As Carbon 41 0.180 133 As propane 206 50.1 0.218 69.62 As Methane 8.76 0.038 9.40 81

Boiler No. 2 Suspension 12/08/99 66,385 116,291 224.70 31.21 42 0.185 As Carbon 42 0.185 144 As propane 232 53.7 0.239 98.29 As Methane 12.20 0.054 9.80 87

Boiler No. 2 Suspension 12/08/99 66,206 119,065 229.80 31.92 44 0.192 As Carbon 44 0.192 156 As propane 228 58.0 0.252 112.31 As Methane 13.90 0.060 8.66 70

Boiler No. 2 Suspension 12/08/99 64,654 119,304 230.78 32.05 61 0.265 As Carbon 61 0.265 209 As propane 304 75.6 0.328 119.47 As Methane 14.44 0.063 8.64 70

Boiler No. 2 Suspension 11/16/00 69,691 118,261 229.68 31.90 3 0.014 As Carbon 3 0.014 59 As propane 98 23.2 0.101 153.10 As Methane 19.94 0.087 10.08 92

Boiler No. 2 Suspension 11/16/00 70,127 121,739 237.01 32.92 2 0.008 As Carbon 2 0.008 90 As propane 144 35.4 0.150 256.08 As Methane 33.57 0.142 9.69 85

Boiler No. 2 Suspension 11/16/00 70,389 126,000 245.29 34.07 5 0.022 As Carbon 5 0.022 134 As propane 198 52.9 0.216 360.17 As Methane 47.39 0.193 8.83 72

Boiler No. 2 Suspension 11/16/01 75,613 121,714 237.30 32.96 38 0.160 As Carbon 38 0.160 167 As propane 249 70.6 0.298 230.40 As Methane 32.56 0.137 8.95 74

Boiler No. 2 Suspension 11/16/01 70,137 121,644 237.18 32.94 20 0.084 As Carbon 20 0.084 108 As propane 166 42.3 0.178 170.14 As Methane 22.30 0.094 9.29 79

Boiler No. 2 Suspension 11/16/01 74,721 120,870 235.12 32.66 28 0.120 As Carbon 28 0.120 136 As propane 219 57.0 0.242 205.32 As Methane 28.68 0.122 9.80 87

Boiler No. 2 Suspension 11/14/02 72,844 124,478 242.19 33.64 69 0.284 As Carbon 69 0.284 257 As propane 428 105.2 0.434 267.49 As Methane 36.42 0.150 10.15 93

Boiler No. 2 Suspension 11/14/02 72,651 119,118 232.17 32.25 57 0.243 As Carbon 57 0.243 253 As propane 419 103.3 0.445 344.64 As Methane 46.80 0.202 10.10 92

Boiler No. 2 Suspension 11/14/02 74,359 120,896 236.60 32.86 80 0.338 As Carbon 80 0.338 312 As propane 517 130.3 0.551 361.41 As Methane 50.23 0.212 10.10 92

Boiler No. 2 Suspension 01/21/04 80,575 125,538 239.94 33.33 49 0.205 As Carbon 49 0.205 111 As propane 187 50.0 0.208 5.27 As Methane 0.79 0.003 10.36 97

Boiler No. 2 Suspension 01/21/04 80,607 131,818 223.87 31.09 151 0.673 As Carbon 151 0.673 500 As propane 763 226.1 1.010 501.01 As Methane 75.49 0.337 9.18 77

Boiler No. 2 Suspension 01/21/04 72,609 134,769 230.06 31.95 107 0.463 As Carbon 107 0.463 443 As propane 673 180.6 0.785 545.82 As Methane 74.08 0.322 9.12 76

Boiler No. 2 Suspension 12/17/04 72,111 111,673 128,571 247.79 34.42 183 0.725 As Carbon 183 0.725 706 As propane 1021 285.5 1.152 761.38 As Methane 102.62 0.414 8.54 68

Boiler No. 2 Suspension 12/17/04 62,186 104,280 116,842 224.22 31.14 75 0.329 As Carbon 75 0.329 310 As propane 469 108.2 0.482 285.65 As Methane 33.20 0.148 9.08 76

Boiler No. 2 Suspension 12/17/04 76,414 117,326 125,915 241.02 33.48 44 0.179 As Carbon 44 0.179 178 As propane 274 76.2 0.316 225.34 As Methane 32.18 0.134 9.30 79

Boiler No. 2 Suspension 12/17/04 71,191 109,338 130,286 249.24 34.62 66 0.261 As Carbon 66 0.261 276 As propane 417 110.4 0.443 330.49 As Methane 43.98 0.176 9.06 75

Boiler No. 2 Suspension 01/27/05 72,664 117,107 133,846 261.40 36.31 49 0.189 As Methane 37 0.142 661 As methane 354 89.8 0.343 389.12 As Methane 52.85 0.202 9.79 87

Boiler No. 2 Suspension 01/27/05 72,357 119,141 139,385 272.20 37.81 77 0.283 As Methane 58 0.212 819 As methane 396 110.8 0.407 393.28 As Methane 53.19 0.195 8.56 68

Boiler No. 2 Suspension 01/27/05 74,303 119,440 141,231 272.70 37.88 49 0.179 As Methane 37 0.134 625 As methane 298 86.8 0.318 361.40 As Methane 50.19 0.184 8.41 66

Boiler No. 2 Suspension 01/17/06 55,850 88,825 145,000 275.60 38.28 28 0.100 As Methane 21 0.075 287 As methane 144 30.0 0.109 84.46 As Methane 8.82 0.032 9.05 75

Boiler No. 2 Suspension 01/17/06 60,485 96,351 141,000 268.10 37.24 33 0.120 As Methane 25 0.090 300 As methane 150 34.0 0.127 82.59 As Methane 9.34 0.035 8.99 74

Boiler No. 2 Suspension 01/17/06 55,840 89,197 149,000 283.10 39.32 29 0.100 As Methane 22 0.075 280 As methane 132 29.2 0.103 73.53 As Methane 7.67 0.027 8.25 64

Boiler No. 2 Suspension 01/17/07 68,734 107,826 140,000 268.75 37.33 21 0.077 As Carbon 21 0.077 60 As propane 94 23.0 0.086 19.16 As Methane 2.46 0.009 9.51 82

Boiler No. 2 Suspension 01/17/07 60,423 94,379 143,333 274.92 38.18 3 0.011 As Carbon 3 0.011 25 As propane 38 8.6 0.031 50.04 As Methane 5.65 0.021 8.96 74

Boiler No. 2 Suspension 01/17/07 65,933 106,028 146,087 278.57 38.69 15 0.055 As Carbon 15 0.055 64 As propane 94 23.6 0.085 67.14 As Methane 8.27 0.030 8.77 71

Boiler No. 2 Suspension 12/20/07 76,291 115,866 133,151 250.42 34.78 17 0.067 As Carbon 17 0.067 68 As propane 108 29.1 0.116 87.26 As Methane 12.45 0.050 9.67 85

Boiler No. 2 Suspension 12/20/07 73,922 113,017 129,167 242.29 33.65 13 0.053 As Carbon 13 0.053 59 As propane 96 24.3 0.100 83.44 As Methane 11.55 0.048 9.95 89

Boiler No. 2 Suspension 12/20/07 74,885 112,738 118,400 220.64 30.64 8 0.038 As Carbon 8 0.038 36 As propane 66 15.0 0.068 48.03 As Methane 6.73 0.030 11.20 113

Boiler No. 2 Suspension 01/14/09 68,866 99,794 134,430 255.81 35.53 25 0.097 As Carbon 25 0.097 65 As propane 120 24.9 0.097 0.00 As Methane 0.02 0.000 11.28 115

Boiler No. 2 Suspension 01/14/09 66,543 100,032 131,392 249.43 34.64 19 0.077 As Carbon 19 0.077 52 As propane 91 19.3 0.077 0.00 As Methane 0.01 0.000 10.71 103

Boiler No. 2 Suspension 01/14/09 65,049 95,582 130,263 248.04 34.45 16 0.063 As Carbon 16 0.063 43 As propane 76 15.6 0.063 0.00 As Methane 0.01 0.000 10.89 107

Number of Runs 41 19 41 41 41 41 41 41 41 41 41 41 41 41 41 41 41 41

n-1 Degrees of Freedom (ν) 40 18 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40

MEAN 69,352 106,207 128,469 245.65 34.12 42.30 0.174 40.68 0.168 232 280 72.3 0.299 241.49 31.64 0.130 9.41 82

MINIMUM 55,840 88,825 116,291 220.64 30.64 1.87 0.008 1.87 0.008 25 38 8.6 0.031 0.00 0.01 0.000 7.51 55

MAXIMUM 80,607 119,440 149,000 283.10 39.32 182.90 0.725 182.90 0.725 819 1,021 285.5 1.152 810.86 102.62 0.414 11.28 115

STD DEVIATION 5,727 10,094 9,162 17.23 2.39 37.87 0.159 37.74 0.160 197 210 58.8 0.249 215.08 27.97 0.115 0.82 13

95% CL OF RUNS 80,805 126,395 146,793 280.10 38.90 118.03 0.493 116.15 0.487 625 701 190.0 0.797 671.64 87.59 0.360 11.06 108

UPL (99% CONFIDENCE) 77,652 122,213 141,748 270.61 37.59 97.18 0.405 95.37 0.400 517 585 157.59 0.660 553.21 72.19 0.297 10.60 101

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 3 Suspension 01/20/98 62,291 95,143 180.58 25.08 150 0.829 As Carbon 150 0.829 712 As Propane 1179 248.9 1.378 851.36 As Methane 99.12 0.549 10.10 92

Boiler No. 3 Suspension 01/20/98 66,663 97,826 185.71 25.79 191 1.027 As Carbon 191 1.027 911 As Propane 1466 340.5 1.833 1,201.65 As Methane 149.73 0.806 9.80 87

Boiler No. 3 Suspension 01/20/98 57,288 95,217 180.77 25.11 308 1.701 As Carbon 308 1.701 1,824 As Propane 2695 586.3 3.243 2,603.33 As Methane 278.76 1.542 8.80 72

Boiler No. 3 Suspension 11/24/98 67,374 104,595 198.56 27.58 15 0.073 As Carbon 15 0.073 288 As Propane 453 108.8 0.548 748.84 As Methane 94.30 0.475 9.53 83

Boiler No. 3 Suspension 11/24/98 71,967 107,727 204.49 28.40 107 0.521 As Carbon 107 0.521 529 As Propane 780 213.7 1.045 796.41 As Methane 107.13 0.524 8.77 71

Boiler No. 3 Suspension 11/24/98 70,315 104,776 198.90 27.63 3 0.014 As Carbon 3 0.014 360 As Propane 538 142.2 0.715 1,060.44 As Methane 139.37 0.701 8.93 74

Boiler No. 3 Suspension 11/22/99 73,842 105,600 201.33 27.96 309 1.535 As Carbon 309 1.535 1,060 As Propane 1573 439.2 2.181 942.26 As Methane 130.05 0.646 8.85 72

Boiler No. 3 Suspension 11/22/99 56,703 99,000 188.32 26.16 254 1.347 As Carbon 254 1.347 1,077 As Propane 1664 342.6 1.819 840.07 As Methane 89.04 0.473 9.33 79

Boiler No. 3 Suspension 11/22/99 74,572 96,923 184.37 25.61 313 1.695 As Carbon 313 1.695 1,055 As Propane 1613 441.3 2.393 923.95 As Methane 128.79 0.699 9.21 78

Boiler No. 3 Suspension 11/22/99 75,961 97,912 186.21 25.86 283 1.521 As Carbon 283 1.521 909 As Propane 1405 387.3 2.080 732.85 As Methane 104.05 0.559 9.34 80

Boiler No. 3 Suspension 12/01/99 72,038 93,506 177.46 24.65 137 0.773 As Carbon 137 0.773 471 As Propane 829 190.1 1.071 392.96 As Methane 52.91 0.298 10.76 104

Boiler No. 3 Suspension 12/01/99 86,351 96,545 182.98 25.41 168 0.916 As Carbon 168 0.916 513 As Propane 879 248.5 1.358 501.03 As Methane 80.87 0.442 10.47 99

Boiler No. 3 Suspension 12/01/99 79,079 99,600 188.90 26.24 76 0.400 As Carbon 76 0.400 233 As Propane 417 103.5 0.548 188.37 As Methane 27.84 0.147 10.90 107

Boiler No. 3 Suspension 01/18/01 78,325 100,000 190.30 26.43 52 0.271 As Carbon 52 0.271 168 As Propane 295 73.6 0.387 150.33 As Methane 22.01 0.116 10.74 104

Boiler No. 3 Suspension 01/18/01 77,687 100,385 190.50 26.46 90 0.470 As Carbon 90 0.470 288 As Propane 521 125.3 0.658 245.58 As Methane 35.66 0.187 11.05 110

Boiler No. 3 Suspension 01/18/01 82,884 104,143 197.60 27.44 113 0.570 As Carbon 113 0.570 331 As Propane 583 153.8 0.779 265.66 As Methane 41.16 0.208 10.76 104

Boiler No. 3 Suspension 11/20/01 78,372 99,333 187.88 26.09 2 0.012 As Carbon 2 0.012 22 As Propane 39 9.5 0.051 49.94 As Methane 7.32 0.039 11.02 110

Boiler No. 3 Suspension 11/20/01 82,637 100,000 189.82 26.36 22 0.118 As Carbon 22 0.118 85 As Propane 149 39.4 0.207 110.17 As Methane 17.02 0.090 10.75 104

Boiler No. 3 Suspension 11/20/01 75,677 101,471 192.07 26.68 29 0.153 As Carbon 29 0.153 123 As Propane 209 52.0 0.271 160.22 As Methane 22.66 0.118 10.42 98

Boiler No. 3 Suspension 12/02/02 73,986 112,059 211.36 29.36 65 0.305 As Carbon 65 0.305 189 As Propane 312 78.4 0.371 100.38 As Methane 13.88 0.066 10.07 92

Boiler No. 3 Suspension 12/02/02 74,798 108,000 203.90 28.32 174 0.851 As Carbon 174 0.851 669 As Propane 1045 280.7 1.377 766.27 As Methane 107.13 0.525 9.46 81

Boiler No. 3 Suspension 12/02/02 76,528 102,985 194.15 26.97 7 0.036 As Carbon 7 0.036 28 As Propane 51 12.1 0.062 36.04 As Methane 5.15 0.027 11.16 113

Boiler No. 3 Suspension 01/13/04 74,779 104,211 195.85 27.20 91 0.462 As Carbon 91 0.462 351 As Propane 714 147.2 0.752 405.67 As Methane 56.70 0.290 12.12 135

Boiler No. 3 Suspension 01/13/04 70,253 105,672 198.53 27.57 189 0.953 As Carbon 189 0.953 664 As Propane 1312 261.5 1.317 551.37 As Methane 72.40 0.365 11.87 129

Boiler No. 3 Suspension 01/13/04 65,493 104,545 196.27 27.26 77 0.390 As Carbon 77 0.390 365 As Propane 743 134.2 0.684 470.66 As Methane 57.62 0.294 12.13 136

Boiler No. 3 Suspension 01/21/05 39,097 62,783 106,452 202.90 28.18 48 0.236 As Methane 36 0.177 1,235 As Methane 700 90.3 0.445 744.30 As Methane 54.39 0.268 10.40 97

Boiler No. 3 Suspension 01/21/05 41,179 65,828 105,000 199.50 27.71 41 0.208 As Methane 31 0.156 972 As Methane 561 74.9 0.375 569.36 As Methane 43.82 0.220 10.58 101

Boiler No. 3 Suspension 01/21/05 39,887 63,766 107,000 203.50 28.26 59 0.288 As Methane 44 0.216 1,338 As Methane 702 100 0.490 750.70 As Methane 55.97 0.275 9.55 83

Boiler No. 3 Suspension 01/18/06 33,302 52,328 108,000 200.20 27.81 31 0.160 As Methane 23 0.120 628 As Methane 369 39.1 0.195 253.02 As Methane 15.75 0.079 10.77 105

Boiler No. 3 Suspension 01/18/06 33,675 52,744 108,000 200.10 27.79 33 0.160 As Methane 24 0.120 636 As Methane 371 40.0 0.200 247.12 As Methane 15.55 0.078 10.69 103

Boiler No. 3 Suspension 01/18/06 35,609 56,260 108,000 200.50 27.85 46 0.230 As Methane 35 0.172 858 As Methane 505 57.1 0.285 339.37 As Methane 22.59 0.113 10.78 105

Boiler No. 3 Suspension 12/07/06 70,900 108,279 96,923 179.00 24.86 90 0.501 As Carbon 90 0.501 495 As Propane 845 197.0 1.101 809.68 As Methane 107.30 0.599 10.42 98

Boiler No. 3 Suspension 12/07/06 69,894 107,118 96,857 178.10 24.74 142 0.798 As Carbon 142 0.798 717 As Propane 1222 281.1 1.578 1,064.24 As Methane 139.03 0.781 10.42 98

Boiler No. 3 Suspension 12/07/06 71,647 109,522 97,500 180.00 25.00 131 0.729 As Carbon 131 0.729 694 As Propane 1162 278.8 1.549 1,101.37 As Methane 147.49 0.819 10.23 94

Boiler No. 3 Suspension 12/19/07 53,156 83,489 101,667 188.87 26.23 93 0.493 As Carbon 93 0.493 647 As Propane 935 192.9 1.021 1,002.79 As Methane 99.75 0.528 8.53 68

Boiler No. 3 Suspension 12/19/07 55,739 89,275 99,740 184.60 25.64 95 0.514 As Carbon 95 0.514 683 As Propane 992 213.7 1.157 1,139.51 As Methane 118.84 0.644 8.58 69

Boiler No. 3 Suspension 12/19/07 55,293 87,147 100,000 184.46 25.62 69 0.373 As Carbon 69 0.373 440 As Propane 666 136.3 0.739 652.25 As Methane 67.49 0.366 9.10 76

Boiler No. 3 Suspension 01/13/09 756,832 88,634 106,479 198.26 27.54 107 0.540 As Carbon 107 0.540 633 As Propane 943 201.9 1.018 892.00 As Methane 94.88 0.479 8.89 73

Boiler No. 3 Suspension 01/13/09 57,500 88,306 107,561 200.14 27.80 65 0.325 As Carbon 65 0.325 380 As Propane 569 122.5 0.612 534.70 As Methane 57.54 0.287 8.97 74

Boiler No. 3 Suspension 01/13/09 57,484 90,796 107,500 200.11 27.79 96 0.481 As Carbon 96 0.481 524 As Propane 770 169.1 0.845 976.10 As Methane 72.75 0.364 8.72 71

Boiler No. 3 Suspension 01/13/09 55,033 88,844 104,800 194.91 27.07 78 0.400 As Carbon 78 0.400 483 As Propane 711 149.2 0.765 692.10 As Methane 71.28 0.366 8.75 71

Number of Runs 40 15 40 40 40 40 40 40 40 40 40 40 40 40 40 40 41 41

n-1 Degrees of Freedom (ν) 39 14 39 39 39 39 39 39 39 39 39 39 39 39 39 39 40 40

MEAN 64,881 80,432 102,304 192.59 26.75 108.42 0.571 106.80 0.563 599 814 182.6 0.962 649.31 75.76 0.399 10.04 93

MINIMUM 33,302 52,328 93,506 177.46 24.65 2.18 0.012 2.18 0.012 22 39 9.5 0.051 36.04 5.15 0.027 8.53 68

MAXIMUM 86,351 109,522 112,059 211.36 29.36 312.50 1.701 312.50 1.701 1,824 2,695 586.3 3.243 2,603.33 278.76 1.542 12.13 136

STD DEVIATION 14,556 20,089 4,597 8.71 1.21 86.69 0.465 87.99 0.471 385 525 130.6 0.709 465.19 54.13 0.296 1.00 18

95% CL OF RUNS 93,994 120,610 111,499 210.01 29.17 281.80 1.500 282.78 1.506 1,368 1,863 443.7 2.381 1,579.68 184.01 0.992 12.05 129

UPL (99% CONFIDENCE) 86,019 113,777 108,980 205.24 28.51 234.31 1.246 234.57 1.247 1,157 1,575 372.18 1.992 1,324.82 154.36 0.830 11.49 119

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 4 Suspension 11/26/97 118,193 233,014 450.10 62.51 55 0.123 As Carbon 55 0.123 109 As Propane 154 72.5 0.161 78.22 As Methane 17.28 0.038 8.20 64

Boiler No. 4 Suspension 11/26/97 110,227 230,417 445.04 61.81 12 0.028 As Carbon 12 0.028 40 As Propane 56 24.6 0.055 60.06 As Methane 12.37 0.028 8.17 63

Boiler No. 4 Suspension 11/26/97 109,762 224,189 432.97 60.13 8 0.018 As Carbon 8 0.018 43 As Propane 59 26.2 0.061 90.06 As Methane 18.48 0.043 8.02 61

Boiler No. 4 Suspension 11/25/98 136,236 253,235 488.47 67.84 36 0.074 As Carbon 36 0.074 211 As Propane 297 161.1 0.330 490.78 As Methane 124.98 0.256 8.20 64

Boiler No. 4 Suspension 11/25/98 125,626 253,235 488.10 67.79 114 0.234 As Carbon 114 0.234 330 As Propane 456 232.2 0.476 502.00 As Methane 117.88 0.241 7.99 61

Boiler No. 4 Suspension 11/25/98 127,392 253,881 490.68 68.15 17 0.035 As Carbon 17 0.035 155 As Propane 221 110.6 0.225 393.23 As Methane 93.63 0.191 8.38 66

Boiler No. 4 Suspension 12/22/98 107,367 245,422 472.99 65.69 164 0.346 As Carbon 164 0.346 675 As Propane 888 406.5 0.859 1,209.11 As Methane 242.65 0.513 7.30 53

Boiler No. 4 Suspension 12/22/98 113,139 251,447 483.50 67.15 134 0.278 As Carbon 134 0.278 410 As Propane 568 260.0 0.538 594.73 As Methane 125.77 0.260 8.00 61

Boiler No. 4 Suspension 12/22/98 113,084 253,151 486.42 67.56 171 0.352 As Carbon 171 0.352 473 As Propane 643 300.3 0.617 610.52 As Methane 129.05 0.265 7.74 58

Boiler No. 4 Suspension 11/24/99 140,315 270,789 521.84 72.48 5 0.010 As Carbon 5 0.010 8.3 As Propane 10 6.5 0.013 5.43 As Methane 1.42 0.003 6.71 47

Boiler No. 4 Suspension 11/24/99 135,887 256,667 494.99 68.75 5 0.010 As Carbon 5 0.010 7.4 As Propane 9.7 5.6 0.011 2.02 As Methane 0.51 0.001 7.26 53

Boiler No. 4 Suspension 11/24/99 137,998 259,091 500.80 69.56 8 0.015 As Carbon 8 0.015 11.6 As Propane 20 8.9 0.018 5.42 As Methane 1.40 0.003 10.50 99

Boiler No. 4 Suspension 11/21/00 129,828 259,259 501.72 69.68 4 0.007 As Carbon 4 0.007 11.7 As Propane 15 8.5 0.017 19.95 As Methane 4.84 0.010 7.13 51

Boiler No. 4 Suspension 11/21/00 129,813 253,151 489.94 68.05 3 0.007 As Carbon 3 0.007 9.7 As Propane 13 7.1 0.014 14.98 As Methane 3.63 0.007 7.17 52

Boiler No. 4 Suspension 11/21/00 135,891 260,282 503.70 69.96 3 0.006 As Carbon 3 0.006 7.3 As Propane 9.8 5.6 0.011 10.06 As Methane 2.55 0.005 7.64 57

Boiler No. 4 Suspension 11/21/01 140,709 250,588 483.73 67.18 4 0.009 As Carbon 4 0.009 5.3 As Propane 7.1 4.2 0.009 0.17 As Methane 0.04 9.0E-05 7.46 55

Boiler No. 4 Suspension 11/21/01 139,232 250,000 483.23 67.12 6 0.012 As Carbon 6 0.012 7.3 As Propane 9.9 5.7 0.012 0.01 As Methane 0.00 3.3E-06 7.66 57

Boiler No. 4 Suspension 11/21/01 141,229 251,642 486.63 67.59 5 0.121 As Carbon 5 0.121 6.3 As Propane 8.6 5.0 0.010 0.04 As Methane 0.01 2.3E-05 7.80 59

Boiler No. 4 Suspension 11/25/02 135,836 261,739 502.97 69.86 5 0.010 As Carbon 5 0.010 11 As Propane 14 8.1 0.016 12.01 As Methane 3.05 0.006 7.55 56

Boiler No. 4 Suspension 11/25/02 130,169 265,217 511.05 70.98 7 0.014 As Carbon 7 0.014 15 As Propane 20 11.1 0.022 16.01 As Methane 3.90 0.008 7.11 51

Boiler No. 4 Suspension 11/25/02 121,508 265,075 510.97 70.97 34 0.067 As Carbon 34 0.067 51 As Propane 65 34.8 0.068 2.11 As Methane 0.48 0.001 6.81 48

Boiler No. 4 Suspension 01/14/04 163,039 272,113 512.93 71.24 45 0.088 As Carbon 45 0.088 71 As Propane 95 64.8 0.126 65.13 As Methane 19.85 0.039 7.57 56

Boiler No. 4 Suspension 01/14/04 156,974 271,538 514.05 71.40 43 0.083 As Carbon 43 0.083 79 As Propane 105 69.3 0.135 90.16 As Methane 26.45 0.051 7.54 56

Boiler No. 4 Suspension 01/14/04 155,072 274,521 520.43 72.28 22 0.042 As Carbon 22 0.042 45 As Propane 60 39.3 0.075 60.09 As Methane 17.42 0.033 7.34 53

Boiler No. 4 Suspension 01/13/05 126,038 203,525 265,000 509.40 70.75 57 0.113 As Methane 43 0.085 268 As Methane 118 63.1 0.124 85.49 As Methane 20.14 0.040 7.35 54

Boiler No. 4 Suspension 01/13/05 117,857 202,508 265,000 508.70 70.65 39 0.076 As Methane 29 0.057 219 As Methane 101 48.3 0.095 87.07 As Methane 19.18 0.038 7.94 60

Boiler No. 4 Suspension 01/13/05 130,959 224,758 270,000 518.30 71.99 58 0.112 As Methane 44 0.084 275 As Methane 118 67.3 0.130 97.19 As Methane 23.79 0.046 7.06 50

Boiler No. 4 Suspension 12/07/05 101,811 169,590 262,418 509.94 70.83 45 0.088 As Carbon 45 0.088 155 As Propane 204 88.6 0.174 230.92 As Methane 43.94 0.086 7.31 53

Boiler No. 4 Suspension 12/07/05 101,639 174,861 268,636 521.10 72.38 70 0.134 As Carbon 70 0.134 165 As Propane 273 94.3 0.181 128.23 As Methane 24.36 0.047 10.06 91

Boiler No. 4 Suspension 12/08/05 120,939 199,867 263,514 511.18 71.00 89 0.175 As Carbon 89 0.175 178 As Propane 233 120.5 0.236 137.96 As Methane 31.19 0.061 7.26 53

Boiler No. 4 Suspension 01/05/07 128,249 217,492 260,000 504.20 70.03 52 0.100 As Methane 39 0.075 161 As Methane 72 116.0 0.230 322.93 As Methane 77.41 0.154 7.63 57

Boiler No. 4 Suspension 01/05/07 134,040 228,265 262,000 501.40 69.64 95 0.190 As Methane 71 0.142 284 As Methane 126 213.7 0.426 569.32 As Methane 142.64 0.284 7.45 55

Boiler No. 4 Suspension 01/05/07 131,102 217,492 256,000 490.90 68.18 49 0.100 As Methane 37 0.075 167 As Methane 75 122.5 0.250 350.88 As Methane 85.98 0.175 7.71 58

Boiler No. 4 Suspension 12/04/07 111,706 202,269 261,000 505.70 70.24 54 0.110 As Methane 40 0.082 193 As Methane 76 120.8 0.239 386.00 As Methane 80.60 0.159 5.70 37

Boiler No. 4 Suspension 12/04/07 114,335 206,945 275,000 531.00 73.75 57 0.110 As Methane 43 0.082 199 As Methane 74 127.9 0.241 399.48 As Methane 85.37 0.161 4.85 30

Boiler No. 4 Suspension 12/04/07 112,448 202,269 263,000 507.50 70.49 60 0.120 As Methane 45 0.090 205 As Methane 75 129.3 0.255 400.79 As Methane 84.24 0.166 4.66 28

Boiler No. 4 Suspension 12/09/08 119,890 208,055 279,000 536.40 74.50 87 0.160 As Methane 65 0.120 291 As Methane 128 195.4 0.364 582.08 As Methane 130.44 0.243 7.34 53

Boiler No. 4 Suspension 12/09/08 119,074 207,666 286,000 550.90 76.51 79 0.140 As Methane 59 0.105 266 As Methane 115 177.6 0.322 532.61 As Methane 118.54 0.215 7.10 51

Boiler No. 4 Suspension 12/09/08 129,646 208,055 290,000 552.50 76.74 74 0.130 As Methane 55 0.097 252 As Methane 110 183.3 0.332 527.77 As Methane 127.89 0.231 7.21 52

Boiler No. 4 Suspension 12/08/09 123,443 215,178 264,000 507.10 70.43 44 0.090 As Methane 33 0.067 142 As Methane 65 98.3 0.194 284.48 As Methane 65.64 0.129 7.79 59

Boiler No. 4 Suspension 12/08/09 125,398 213,497 265,000 509.00 70.69 46 0.090 As Methane 35 0.067 148 As Methane 65 104.3 0.205 296.95 As Methane 69.60 0.137 7.40 54

Boiler No. 4 Suspension 12/08/09 119,828 215,178 274,000 527.40 73.25 46 0.090 As Methane 34 0.067 157 As Methane 65 105.4 0.200 316.74 As Methane 70.94 0.135 6.57 45

Number of Runs 42 18 42 42 42 42 42 36 36 42 42 36 36 36 36 36 42 42

n-1 Degrees of Freedom (ν) 41 17 41 41 41 41 41 35 35 41 41 35 35 35 35 35 41 41

MEAN 126,736 206,526 260,696 501.90 69.71 47.87 0.098 41.79 0.088 155 140 88.6 0.179 209.13 46.85 0.095 7.47 56

MINIMUM 101,639 169,590 224,189 432.97 60.13 3.01 0.006 3.01 0.006 5.3 7.1 4.2 0.009 0.01 0.002 3.3E-06 4.66 28

MAXIMUM 163,039 228,265 290,000 552.50 76.74 171.22 0.352 171.22 0.352 675 888 406.5 0.859 1,209.11 242.65 0.513 10.50 99

STD DEVIATION 13,884 14,798 13,048 24.02 3.34 42.45 0.086 44.02 0.090 145 185 94.9 0.197 263.51 56.65 0.117 0.99 12

95% CL OF RUNS 154,504 236,122 286,791 549.94 76.38 132.77 0.269 129.84 0.268 445 511 278.4 0.572 736.15 160.15 0.329 9.45 80

UPL (99% CONFIDENCE) 146,822 230,214 279,572 536.65 74.53 109.28 0.222 106.28 0.220 365 408 227.63 0.467 595.14 129.84 0.266 8.90 73

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 5 Suspension 12/02/97 86,574 188,028 366.11 50.85 2 0.006 As Carbon 2.28 0.006 11 As Propane 15 5.52 0.015 20.00 As Methane 3.24 0.009 7.06 50

Boiler No. 5 Suspension 12/02/97 84,007 195,652 381.91 53.04 2 0.005 As Carbon 2 0.005 11 As Propane 16 5.40 0.014 22.01 As Methane 3.46 0.009 7.69 57

Boiler No. 5 Suspension 12/02/97 84,602 202,174 395.01 54.86 4 0.011 As Carbon 4 0.011 21 As Propane 26 9.82 0.025 35.06 As Methane 5.54 0.014 6.75 47

Boiler No. 5 Suspension 12/01/98 78,380 193,478 377.56 52.44 6 0.016 As Carbon 6 0.016 108 As Propane 127 47.43 0.126 281.62 As Methane 41.26 0.109 5.74 37

Boiler No. 5 Suspension 12/01/98 73,663 195,833 382.20 53.08 3 0.008 As Carbon 3 0.008 177 As Propane 203 73.07 0.191 508.33 As Methane 69.99 0.183 5.34 34

Boiler No. 5 Suspension 12/01/98 86,665 199,286 389.33 54.07 31 0.081 As Carbon 31 0.081 326 As Propane 357 158.67 0.408 785.47 As Methane 127.24 0.327 4.52 27

Boiler No. 5 Suspension 11/30/99 99,933 191,667 370.20 51.42 9 0.024 As Carbon 9 0.024 21 As Propane 31 11.62 0.031 14.22 As Methane 2.66 0.007 8.85 72

Boiler No. 5 Suspension 11/30/99 97,885 197,917 382.16 53.08 10 0.025 As Carbon 10 0.025 24 As Propane 33 13.04 0.034 18.94 As Methane 3.47 0.009 8.17 63

Boiler No. 5 Suspension 11/30/99 96,860 202,817 391.62 54.39 13 0.033 As Carbon 13 0.033 32 As Propane 45 17.41 0.044 24.88 As Methane 4.50 0.012 8.19 64

Boiler No. 5 Suspension 11/28/00 106,606 194,400 380.16 52.80 10 0.026 As Carbon 10 0.026 35 As Propane 51 20.69 0.054 55.01 As Methane 10.96 0.029 8.85 72

Boiler No. 5 Suspension 11/28/00 99,637 197,027 385.31 53.52 16 0.041 As Carbon 16 0.041 49 As Propane 70 27.11 0.070 59.97 As Methane 11.17 0.029 8.47 67

Boiler No. 5 Suspension 11/28/00 102,422 190,244 372.10 51.68 24 0.063 As Carbon 24 0.063 68 As Propane 98 38.95 0.105 80.05 As Methane 15.32 0.041 8.56 68

Boiler No. 5 Suspension 12/05/01 105,971 203,077 394.45 54.78 13 0.033 As Carbon 13 0.033 36 As Propane 54 21.64 0.055 43.06 As Methane 8.53 0.022 8.93 74

Boiler No. 5 Suspension 12/05/01 106,367 190,588 368.74 51.21 12 0.034 As Carbon 12 0.034 33 As Propane 50 19.45 0.053 35.02 As Methane 6.96 0.019 9.20 78

Boiler No. 5 Suspension 12/05/01 105,938 200,000 387.16 53.77 14 0.036 As Carbon 14 0.036 42 As Propane 62 24.78 0.064 55.10 As Methane 10.91 0.028 8.90 73

Boiler No. 5 Suspension 11/26/02 103,951 172,703 334.51 46.46 3 0.010 As Carbon 3 0.010 8.2 As Propane 14 4.76 0.014 8.02 As Methane 1.56 0.005 10.39 97

Boiler No. 5 Suspension 11/27/02 103,313 186,269 360.58 50.08 3 0.008 As Carbon 3 0.008 9.1 As Propane 14 5.27 0.015 12.00 As Methane 2.32 0.006 9.59 84

Boiler No. 5 Suspension 11/27/02 100,621 196,765 381.72 53.02 16 0.043 As Carbon 16 0.043 59 As Propane 84 33.41 0.088 91.08 As Methane 17.13 0.045 8.23 64

Boiler No. 5 Suspension 01/16/04 119,054 188,060 359.32 49.91 25 0.069 As Carbon 25 0.069 62 As Propane 102 41.68 0.116 75.14 As Methane 16.72 0.047 9.96 90

Boiler No. 5 Suspension 01/16/04 115,545 197,647 378.32 52.54 46 0.122 As Carbon 46 0.122 116 As Propane 181 75.30 0.199 135.22 As Methane 29.20 0.077 9.44 81

Boiler No. 5 Suspension 01/16/04 115,187 195,224 374.04 51.95 38 0.100 As Carbon 38 0.100 85 As Propane 133 54.77 0.146 80.16 As Methane 17.26 0.046 9.55 83

Boiler No. 5 Suspension 01/12/05 109,098 177,189 191,000 372.90 51.79 53 0.142 As Methane 40 0.142 524 As Methane 289 106.91 0.287 330.08 As Methane 67.31 0.181 10.08 92

Boiler No. 5 Suspension 01/12/05 109,727 179,165 201,000 391.10 54.32 50 0.128 As Methane 37 0.128 444 As Methane 238 91.08 0.233 261.83 As Methane 53.70 0.137 9.78 87

Boiler No. 5 Suspension 01/12/05 109,098 178,457 206,000 400.50 55.63 54 0.134 As Methane 40 0.100 530 As Methane 263 108.03 0.270 332.43 As Methane 67.79 0.169 8.88 73

Boiler No. 5 Suspension 12/09/05 114,313 177,618 177,568 347.28 48.23 27 0.077 As Carbon 27 0.077 50 As Propane 83 32.06 0.092 25.10 As Methane 5.36 0.015 10.14 93

Boiler No. 5 Suspension 12/09/05 114,812 179,184 184,225 359.87 49.98 26 0.073 As Carbon 26 0.073 48 As Propane 78 30.70 0.085 20.09 As Methane 4.31 0.012 9.95 89

Boiler No. 5 Suspension 12/09/05 116,552 180,445 184,167 360.19 50.03 22 0.062 As Carbon 22 0.062 42 As Propane 68 27.19 0.075 22.09 As Methane 4.81 0.013 9.97 90

Boiler No. 5 Suspension 01/09/07 108,149 167,923 182,000 354.40 49.22 43 0.120 As Methane 32 0.090 160 As Methane 95 32.43 0.092 0.37 As Methane 0.08 0.0002 10.80 105

Boiler No. 5 Suspension 01/09/07 105,550 164,818 192,000 372.80 51.78 48 0.130 As Methane 36 0.097 182 As Methane 104 36.00 0.097 0.42 As Methane 0.08 0.0002 10.41 98

Boiler No. 5 Suspension 01/09/07 106,209 167,923 177,000 341.60 47.44 45 0.130 As Methane 34 0.097 170 As Methane 98 33.72 0.099 0.41 As Methane 0.08 0.0002 10.60 101

Boiler No. 5 Suspension 12/06/07 99,772 162,742 190,000 369.30 51.29 91 0.250 As Methane 68 0.187 366 As Methane 190 68.36 0.185 0.90 As Methane 0.17 0.0005 9.38 80

Boiler No. 5 Suspension 12/06/07 95,485 167,285 192,000 374.90 52.07 147 0.390 As Methane 110 0.292 618 As Methane 293 110.38 0.294 1.48 As Methane 0.26 0.0007 8.31 65

Boiler No. 5 Suspension 12/06/07 100,535 162,742 179,000 348.80 48.44 57 0.160 As Methane 43 0.120 227 As Methane 120 42.69 0.122 0.59 As Methane 0.11 0.0003 9.66 85

Boiler No. 5 Suspension 12/11/08 83,091 137,485 183,000 358.30 49.76 205 0.570 As Methane 153 0.427 990 As Methane 463 153.85 0.429 2.41 As Methane 0.37 0.0010 8.15 63

Boiler No. 5 Suspension 12/11/08 80,369 136,114 186,000 364.50 50.63 153 0.420 As Methane 115 0.314 766 As Methane 342 115.07 0.316 1.85 As Methane 0.28 0.0008 7.55 56

Boiler No. 5 Suspension 12/11/08 80,974 137,485 187,000 366.60 50.92 214 0.580 As Methane 160 0.434 1060 As Methane 498 160.51 0.438 2.53 As Methane 0.38 0.0010 8.22 64

Boiler No. 5 Suspension 12/10/09 87,746 132,107 182,000 354.10 49.18 93 0.260 As Methane 70 0.195 426 As Methane 233 69.92 0.197 1.02 As Methane 0.17 0.0005 10.00 90

Boiler No. 5 Suspension 12/10/09 83,316 136,638 184,000 356.80 49.56 59 0.170 As Methane 44 0.127 285 As Methane 156 44.44 0.125 0.69 As Methane 0.11 0.0003 10.00 90

Boiler No. 5 Suspension 12/10/09 83,120 136,742 186,000 360.60 50.08 63 0.170 As Methane 47 0.127 304 As Methane 166.3 47.30 0.131 0.70 As Methane 0.11 0.0003 10.00 90

Number of Runs 39 18 39 39 39 39 39 39 39 39 39 39 39 39 39 39 39 39

n-1 Degrees of Freedom (ν) 38 17 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38

MEAN 99,002 160,115 190,841 370.95 51.52 44.90 0.122 36.04 0.100 219 142 51.81 0.139 88.34 15.77 0.0412 8.83 74

MINIMUM 73,663 132,107 172,703 334.51 46.46 1.94 0.005 1.94 0.005 8.2 13.9 4.76 0.014 0.37 0.08 0.0002 4.52 27

MAXIMUM 119,054 180,445 206,000 400.50 55.63 213.86 0.580 160.13 0.434 1,060 498 160.51 0.438 785.47 127.24 0.3268 10.80 105

STD DEVIATION 12,431 18,416 8,044 15.55 2.16 52.69 0.144 38.59 0.106 271 123 43.71 0.117 162.32 27.01 0.0697 1.45 19

95% CL OF RUNS 123,865 196,947 206,930 402.05 55.84 150.27 0.411 113.22 0.312 760 388 139.24 0.373 412.97 69.78 0.1806 11.73 112

UPL (99% CONFIDENCE) 117,091 189,594 202,546 393.58 54.66 121.56 0.332 92.19 0.254 613 321 115.41 0.309 324.52 55.07 0.143 10.94 101

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 8 Suspension 12/04/98 112,054 243,971 469.04 65.14 1 0.003 As Carbon 1 0.003 25 As Propane 38 15.90 0.034 69.88 As Methane 14.64 0.031 8.87 73

Boiler No. 8 Suspension 12/04/98 110,893 243,478 469.29 65.18 1 0.003 As Carbon 1 0.003 21 As Propane 33 13.24 0.028 57.62 As Methane 11.94 0.025 9.24 78

Boiler No. 8 Suspension 12/04/98 112,672 255,652 494.06 68.62 2 0.004 As Carbon 2 0.004 32 As Propane 46 20.14 0.041 86.06 As Methane 18.12 0.037 8.46 67

Boiler No. 8 Suspension 02/24/99 122,911 169,690 240,882 464.51 64.52 11 0.024 As Carbon 11 0.024

Boiler No. 8 Suspension 02/24/99 109,390 157,285 244,478 471.75 65.52 4 0.009 As Carbon 4 0.009

Boiler No. 8 Suspension 02/24/99 110,580 162,280 238,000 458.86 63.73 8 0.017 As Carbon 8 0.017

Boiler No. 8 Suspension 12/11/01 147,986 250,588 486.69 67.60 65 0.133 As Carbon 65 0.133 111 As Propane 180 91.90 0.189 98.14 As Methane 27.15 0.056 9.89 88

Boiler No. 8 Suspension 12/11/01 144,769 258,529 501.41 69.64 44 0.088 As Carbon 44 0.088 87 As Propane 136 70.49 0.141 98.01 As Methane 26.52 0.053 9.45 81

Boiler No. 8 Suspension 12/11/01 142,486 261,176 506.68 70.37 52 0.102 As Carbon 52 0.102 97 As Propane 149 77.85 0.154 98.08 As Methane 26.12 0.052 9.24 78

Boiler No. 8 Suspension 12/17/02 126,124 267,200 518.27 71.98 18 0.035 As Carbon 18 0.035 44 As Propane 63 30.99 0.060 55.48 As Methane 13.08 0.025 8.50 67

Boiler No. 8 Suspension 12/17/02 121,702 269,600 523.56 72.72 25 0.047 As Carbon 25 0.047 42 As Propane 61 28.99 0.055 18.58 As Methane 4.23 0.008 8.55 68

Boiler No. 8 Suspension 12/17/02 123,394 256,667 498.68 69.26 43 0.087 As Carbon 43 0.087 66 As Propane 96 45.57 0.091 9.14 As Methane 2.11 0.004 8.65 70

Boiler No. 8 Suspension 2/13/20046114,061 184,796 249,429 484.00 67.22 12 0.026 As Methane 9 0.019 44 As Methane 20 28.03 0.058 87.80 As Methane 18.72 0.039 8.05 62

Boiler No. 8 Suspension 2/13/20046115,849 185,616 250,400 484.80 67.33 11 0.022 As Methane 8 0.016 37 As Methane 18 24.11 0.050 74.31 As Methane 16.09 0.033 8.29 65

Boiler No. 8 Suspension 2/13/20046117,531 184,920 249,231 481.60 66.89 11 0.023 As Methane 8 0.017 38 As Methane 17 24.79 0.051 75.39 As Methane 16.56 0.034 8.02 61

Boiler No. 8 Suspension 01/19/05 123,423 191,937 261,136 507.60 70.50 62 0.123 As Methane 47 0.092 547 As Methane 251 126.27 0.249 344.83 As Methane 79.55 0.157 7.93 60

Boiler No. 8 Suspension 01/19/05 115,669 185,579 268,000 519.60 72.17 63 0.120 As Methane 47 0.090 695 As Methane 306 150.24 0.289 478.19 As Methane 103.39 0.199 7.38 54

Boiler No. 8 Suspension 01/19/05 123,423 191,937 270,000 523.50 72.71 111 0.213 As Methane 83 0.159 773 As Methane 339 178.42 0.341 411.90 As Methane 95.02 0.182 7.32 53

Boiler No. 8 Suspension 01/20/06 101,378 161,441 270,000 513.60 71.33 20 0.040 As Methane 15 0.030 112 As Methane 47 21.27 0.041 33.37 As Methane 6.32 0.012 6.77 47

Boiler No. 8 Suspension 01/20/06 97,668 155,534 271,000 519.30 72.13 30 0.060 As Methane 23 0.045 162 As Methane 65 29.66 0.057 39.03 As Methane 7.12 0.014 6.10 41

Boiler No. 8 Suspension 01/20/06 101,378 161,441 267,000 509.10 70.71 45 0.090 As Methane 34 0.067 257 As Methane 106 48.71 0.096 77.32 As Methane 14.65 0.029 6.38 43

Boiler No. 8 Suspension 01/11/07 101,634 164,590 279,000 532.20 73.92 61 0.120 As Methane 46 0.090 243 As Methane 105 46.12 0.087 0.63 As Methane 0.12 0.000 7.13 51

Boiler No. 8 Suspension 01/11/07 105,031 170,731 275,000 526.30 73.10 62 0.120 As Methane 47 0.090 238 As Methane 102 46.66 0.089 0.54 As Methane 0.11 0.000 7.00 50

Boiler No. 8 Suspension 01/11/07 105,997 164,590 278,000 530.90 73.74 67 0.126 As Methane 50 0.094 253 As Methane 111 50.09 0.094 0.42 As Methane 0.08 0.000 7.29 53

Boiler No. 8 Suspension 12/10/07 134,976 213,653 270,000 519.30 72.13 92 0.180 As Methane 69 0.135 273 As Methane 145 68.95 0.133 0.62 As Methane 0.16 0.000 9.65 84

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Sugar Cane Growers Cooperative of Florida

Boiler MACT Database Facility ID: FLSugarCaneGrowersCoop

THC Emissions Methane Emissions

Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) (EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Reported 4 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

ppm @ 3% 

O2 as Propane

Boiler No. 8 Suspension 12/10/07 132,039 209,109 265,000 511.10 70.99 118 0.230 As Methane 88 0.172 359 As Methane 189 88.54 0.173 0.84 As Methane 0.21 0.000 9.57 83

Boiler No. 8 Suspension 12/10/07 131,690 213,653 260,000 499.60 69.39 120 0.240 As Methane 90 0.180 406 As Methane 213 100.02 0.200 40.60 As Methane 9.99 0.020 9.53 82

Boiler No. 8 Suspension 12/16/08 127,985 205,572 276,000 532.10 73.90 136 0.260 As Methane 102 0.195 428 As Methane 232 102.31 0.192 1.05 As Methane 0.25 0.000 9.91 89

Boiler No. 8 Suspension 12/16/08 124,586 201,481 270,000 520.10 72.24 112 0.210 As Methane 84 0.157 360 As Methane 187 83.91 0.161 0.90 As Methane 0.21 0.000 9.42 81

Boiler No. 8 Suspension 12/16/08 123,076 205,572 280,000 538.20 74.75 107 0.200 As Methane 80 0.150 361 As Methane 183 83.10 0.154 13.30 As Methane 3.06 0.006 9.15 77

Boiler No. 8 Suspension 12/28/09 134,267 200,488 278,000 535.30 74.35 100 0.187 As Methane 75 0.140 299 As Methane 181 74.97 0.140 0.71 As Methane 0.18 0.000 11.09 111

Boiler No. 8 Suspension 12/28/09 132,280 202,808 284,000 545.40 75.75 113 0.207 As Methane 85 0.155 343 As Methane 201 84.75 0.155 0.83 As Methane 0.20 0.000 10.74 104

Boiler No. 8 Suspension 12/28/09 132,664 201,467 275,000 528.30 73.38 89 0.168 As Methane 66 0.126 299 As Methane 177 74.27 0.141 31.84 As Methane 7.90 0.015 10.82 105

Number of Runs 33 24 33 33 33 33 33 33 33 30 30 30 30 30 30 30 30 30

n-1 Degrees of Freedom (ν) 32 23 32 32 32 32 32 32 32 29 29 29 29 29 29 29 29 29

MEAN 120,654 185,257 262,922 506.81 70.39 55 0.107 43 0.084 235 133 64.34 0.125 76.85 17.46 0.034 8.61 71

MINIMUM 97,668 155,534 238,000 458.86 63.73 1 0.003 1 0.003 21 17 13.24 0.028 0.42 0.08 0.000 6.10 41

MAXIMUM 147,986 213,653 284,000 545.40 75.75 136 0.260 102 0.195 773 339 178.42 0.341 478.19 103.39 0.199 11.09 111

STD DEVIATION 13,128 19,559 12,840 23.66 3.29 42 0.081 31 0.060 200 86 40.76 0.078 120.12 27.08 0.052 1.31 18

95% CL OF RUNS 146,910 224,375 288,602 554.13 76.96 140 0.268 106 0.204 635 305 145.85 0.281 317.08 71.62 0.139 11.24 107

UPL (99% CONFIDENCE) 140,039 215,199 281,882 541.74 75.24 118 0.226 90 0.173 533 262 125.10 0.241 255.92 57.83 0.112 10.57 98

Notes:

lb/hr = pounds per hour.

lb/MMBtu = pounds per million British thermal units.

lb/ton = pounds per ton.

MMBtu/hr = million British thermal units per hour.

TPH = tons per hour.

Footnotes:

1 Assumed 3,600 Btu/lb average heat content for wet bagasse, except where noted.

2

 Based on actual reported data.

3

If reported as propane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as propane x ((3*12.011)/44.09) 

 where 44.09 is the MW of propane and 12.011 is the MW of carbon.

 If reported as methane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as methane x (12.011/16.04) 

 where 16.04 is the MW of methane and 12.011 is the MW of carbon.

4 As reported in test report.

5

If necessary, converted basis to as carbon.

6 Firing fuel oil concurrently with bagasse.

7

 Run 1 was excluded from the averages due to boiler upset during the run.

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLSugarCaneGrowersCoop 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Osceola Farms Company

Boiler MACT Database Facility ID: FLOsceolaFarms

THC Emissions Methane Emissions

N/S or Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) 6(EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type E/W Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Blr. Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm 

6

Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

Boiler No. 2 Suspension 01/14/99 74,291 128,000 252.2 35.03 4 0.014 As methane 3 0.010 21 As methane 8.8 2.9 0.012 1.82 As Methane 0.25 0.001 6.72 47

Boiler No. 2 Suspension 01/14/99 73,743 126,720 249.7 34.68 4 0.014 As methane 3 0.010 22 As methane 9.0 3.0 0.012 2.68 As Methane 0.37 0.001 6.43 44

Boiler No. 2 Suspension 01/14/99 74,453 131,200 258.4 35.89 3 0.013 As methane 3 0.010 21 As methane 9.0 2.9 0.011 2.92 As Methane 0.41 0.002 6.93 48

Boiler No. 2 Suspension 11/17/99 83,407 140,000 274.5 38.12 144 0.482 As methane 108 0.361 752 As methane 328 117.3 0.427 61.40 As Methane 9.57 0.035 7.22 52

Boiler No. 2 Suspension 11/17/99 82,363 134,400 263.6 36.61 15 0.058 As methane 12 0.043 83 As methane 35 12.7 0.048 7.68 As Methane 1.18 0.004 6.87 49

Boiler No. 2 Suspension 11/17/99 82,456 136,800 267.8 37.20 31 0.122 As methane 24 0.091 172 As methane 73 26.6 0.099 19.82 As Methane 3.05 0.011 6.79 48

Boiler No. 2 Suspension 11/15/00 77,327 129,600 252.4 35.06 116 0.464 As methane 87 0.347 631 As methane 302 91.3 0.362 32.69 As Methane 4.72 0.019 8.45 66

Boiler No. 2 Suspension 11/15/00 76,582 128,800 250.8 34.83 107 0.424 As methane 80 0.317 582 As methane 261 83.4 0.332 23.25 As Methane 3.33 0.013 7.61 56

Boiler No. 2 Suspension 11/15/00 76,441 127,200 247.9 34.43 119 0.471 As methane 89 0.353 647 As methane 282 92.5 0.373 24.31 As Methane 3.47 0.014 7.21 51

Boiler No. 2 Suspension 11/26/01 76,424 140,000 275.6 38.27 104 0.379 As methane 78 0.284 573 As methane 265 81.9 0.297 28.88 As Methane 4.13 0.015 8.01 61

Boiler No. 2 Suspension 11/26/01 75,972 137,600 270.7 37.59 112 0.420 As methane 84 0.314 612 As methane 291 86.9 0.321 20.13 As Methane 2.86 0.011 8.36 66

Boiler No. 2 Suspension 11/26/01 75,225 140,000 275.5 38.26 119 0.435 As methane 89 0.326 661 As methane 317 92.9 0.337 25.47 As Methane 3.58 0.013 8.49 68

Boiler No. 2 Suspension 11/20/02 75,613 124,800 245.0 34.02 110 0.457 As methane 83 0.342 613 As methane 340 86.7 0.354 28.73 As Methane 4.06 0.017 10.16 94

Boiler No. 2 Suspension 11/20/02 75,849 125,600 247.0 34.31 100 0.386 As methane 75 0.289 551 As methane 296 78.1 0.316 24.84 As Methane 3.52 0.014 9.81 87

Boiler No. 2 Suspension 11/20/02 74,074 129,600 254.9 35.40 110 0.393 As methane 82 0.294 618 As methane 337 85.6 0.336 23.16 As Methane 3.21 0.013 9.99 91

Boiler No. 2 Suspension 12/11/03 77,490 118,576 232.9 32.34 95 0.421 As methane 71 0.315 550 As methane 256 79.7 0.342 56.32 As Methane 8.16 0.035 8.10 63

Boiler No. 2 Suspension 12/11/03 76,191 123,060 241.7 33.56 26 0.109 As methane 20 0.082 147 As methane 73 20.9 0.087 8.37 As Methane 1.19 0.005 8.95 75

Boiler No. 2 Suspension 12/11/03 73,673 123,323 241.8 33.58 38 0.158 As methane 29 0.118 210 As methane 102 28.9 0.119 0.57 As Methane 0.08 0.000 8.70 71

Boiler No. 2 Suspension 11/30/04-12/01/04 58,635 93,925 114,409 224.5 31.18 206 0.914 As methane 154 0.684 1406 As methane 647 154.2 0.687 2.11 As Methane 0.23 0.001 7.94 61

Boiler No. 2 Suspension 11/30/04-12/01/04 62,100 99,107 115,939 227.2 31.56 55 0.244 As methane 41 0.183 346 As methane 161 40.2 0.177 0.00 As Methane 0.00 0.000 8.07 63

Boiler No. 2 Suspension 11/30/04-12/01/04 59,697 94,763 114,567 224.2 31.14 92 0.409 As methane 69 0.306 614 As methane 279 68.6 0.306 0.00 As Methane 0.00 0.000 7.78 59

Boiler No. 2 Suspension 01/10/06 56,496 86,964 128,720 254.0 35.27 44 0.172 As methane 33 0.129 387 As methane 178 40.8 0.161 76.23 As Methane 8.05 0.032 7.99 62

Boiler No. 2 Suspension 01/10/06 56,956 85,281 126,322 248.7 34.54 41 0.163 As methane 31 0.122 493 As methane 216 52.6 0.211 206.97 As Methane 22.03 0.089 7.29 53

Boiler No. 2 Suspension 01/10/06 59,591 89,652 121,071 238.9 33.18 20 0.082 As methane 15 0.061 209 As methane 95 23.3 0.097 77.75 As Methane 8.66 0.036 7.76 59

Boiler No. 2 Suspension 11/30/06 75,714 120,035 133,093 263.6 36.60 121 0.460 As methane 90 0.344 644 As methane 290 91.2 0.346 5.64 As Methane 0.80 0.003 7.68 58

Boiler No. 2 Suspension 11/30/06 72,697 115,645 131,634 260.7 36.20 76 0.300 As methane 57 0.225 428 As methane 200 58.1 0.223 6.90 As Methane 0.94 0.004 8.18 64

Boiler No. 2 Suspension 11/30/06 70,264 112,047 132,967 263.3 36.57 102 0.380 As methane 76 0.285 591 As methane 268 77.7 0.295 10.50 As Methane 1.38 0.005 7.74 58

Boiler No. 2 Suspension 11/13/07-11/14/07 62,013 99,466 128,166 254.4 35.33 99 0.390 As methane 74 0.292 653 As methane 268 75.7 0.298 10.28 As Methane 1.19 0.005 6.37 44

Boiler No. 2 Suspension 11/13/07-11/14/07 63,210 99,207 126,026 249.5 34.65 74 0.290 As methane 55 0.217 498 As methane 211 58.8 0.236 28.38 As Methane 3.35 0.013 6.81 48

Boiler No. 2 Suspension 11/13/07-11/14/07 62,251 99,963 130,282 258.1 35.85 105 0.400 As methane 79 0.300 701 As methane 283 81.6 0.316 25.05 As Methane 2.92 0.011 6.11 41

Boiler No. 2 Suspension 11/18/08-11/19/08 66,071 99,190 130,289 256.8 35.67 73 0.280 As methane 55 0.210 524 As methane 280 64.7 0.252 82.33 As Methane 10.17 0.040 9.74 87

Boiler No. 2 Suspension 11/18/08-11/19/08 72,107 107,299 127,099 248.6 34.53 63 0.260 As methane 47 0.195 355 As methane 165 47.8 0.192 2.91 As Methane 0.39 0.002 8.10 63

Boiler No. 2 Suspension 11/18/08-11/19/08 67,715 100,016 126,774 248.9 34.57 60 0.240 As methane 45 0.180 371 As methane 179 47.0 0.189 19.26 As Methane 2.44 0.010 8.56 69

Boiler No. 2 Suspension 11/17/09-11/18/09 61,735 99,123 116,345 227.0 31.53 230 1.010 As methane 172 0.756 1,544 As methane 589 178.2 0.785 53.22 As Methane 6.14 0.027 5.26 33

Boiler No. 2 Suspension 11/17/09-11/18/09 62,024 98,284 115,954 225.9 31.37 124 0.550 As methane 93 0.412 803 As methane 319 93.2 0.413 4.59 As Methane 0.53 0.002 5.89 39

Boiler No. 2 Suspension 11/17/09-11/18/09 58,481 93,459 119,723 233.6 32.44 127 0.540 As methane 95 0.404 874 As methane 348 95.5 0.409 3.30 As Methane 0.36 0.002 5.93 39

Number of Runs 36 18 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36

n-1 Degrees of Freedom (ν) 35 17 35 35 35 35 35 35 35 35 35 35 35 35 35 35 35 35

MEAN 70,259 99,635 127,352 250 35 85 0.342 64 0.256 525 238 67 0.272 28 4 0.014 8 59

MINIMUM 56,496 85,281 114,409 224 31 3 0.013 3 0.010 21 9 3 0.011 0 0 0.000 5 33

MAXIMUM 83,407 120,035 140,000 276 38 230 1.010 172 0.756 1,544 647 178 0.785 207 22 0.089 10 94

STD DEVIATION 7,980 9,232 7,149 15 2 52 0.219 39 0.164 327 139 39 0.166 38 4 0.017 1 15

95% CL OF RUNS 86,219 118,100 141,649 279.3 38.79 189.14 0.780 141.62 0.584 1,180 517 145.7 0.604 104.91 12.10 0.048 10.08 89

UPL (99% CONFIDENCE) 81,949 114,414 137,824 272 37.71 161.34 0.663 120.80 0.496 1,005 442 124.7 0.515 84.34 9.81 0.039 9 81

Boiler No. 3 Suspension 11/22/04 51,186 76,171 112,985 222.6 30.92 45 0.204 As Methane 34 0.153 748 As methane 391 71.6 0.321 392.12 As Methane 37.52 0.169 9.50 83

Boiler No. 3 Suspension 11/22/04 50,572 74,446 128,250 251.9 34.99 34 0.133 As Methane 25 0.100 555 As methane 293 52.5 0.208 289.25 As Methane 27.34 0.109 9.60 84

Boiler No. 3 Suspension 11/22/04 51,535 76,584 112,629 221.1 30.71 35 0.159 As Methane 26 0.119 568 As methane 284 54.7 0.248 295.77 As Methane 28.49 0.129 9.00 75

Boiler No. 3 Suspension 12/15/05 45,337 71,359 128,949 256.3 35.60 26 0.102 As Methane 20 0.076 572 As methane 235 48.5 0.189 341.24 As Methane 28.92 0.113 6.39 44

Boiler No. 3 Suspension 12/15/05 44,762 71,625 129,971 258.7 35.93 36 0.138 As Methane 27 0.103 1152 As methane 475 96.4 0.373 832.06 As Methane 69.62 0.269 6.44 44

Boiler No. 3 Suspension 12/15/05 44,474 72,172 137,324 272.3 37.82 53 0.194 As Methane 39 0.145 739 As methane 309 61.4 0.226 263.75 As Methane 21.92 0.081 6.66 46

Boiler No. 3 Suspension 11/28/06 44,317 74,363 120,837 239.5 33.26 53 0.220 As Methane 39 0.165 863 As methane 328 71.5 0.299 387.33 As Methane 32.08 0.134 5.21 33

Boiler No. 3 Suspension 11/28/06 42,733 72,591 119,679 237.4 32.97 48 0.200 As Methane 36 0.150 871 As methane 326 69.6 0.293 421.63 As Methane 33.68 0.142 4.96 31

Boiler No. 3 Suspension 11/28/06 43,050 74,363 115,845 229.5 31.88 43 0.190 As Methane 32 0.142 885 As methane 342 71.2 0.310 483.36 As Methane 38.89 0.169 5.48 35

Number of Runs 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9

n-1 Degrees of Freedom (ν) 8 8 8 8 8 8 8 8 8 8 8 8 -1 8 8 8 8 8

MEAN 46,441 73,742 122,941 243 34 41 0.171 31 0.128 772 331 66 412 35 0.146 7 53

MINIMUM 42,733 71,359 112,629 221 31 26 0.102 20 0.076 555 235 48 264 22 0.081 5 31

MAXIMUM 51,535 76,584 137,324 272 38 53 0.220 39 0.165 1,152 475 96 832 70 0.269 10 84

STD DEVIATION 3,592 1,910 8,598 18 2 9 0.040 7 0.030 195 69 14 173 14 0.054 2 22

95% CL OF RUNS 53,624 77,562 140,138 278.5 38.68 59.88 0.251 44.83 0.188 1,163 469 95.2 0.000 756.95 63.11 0.254 10.73 96

UPL (99% CONFIDENCE) 53,376 77,430 139,544 277 38.51 59.24 0.248 44.36 0.186 1,150 464 94.2 #NUM! 745.03 62.16 0.251 11 95

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLOsceolaFarms 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Osceola Farms Company

Boiler MACT Database Facility ID: FLOsceolaFarms

THC Emissions Methane Emissions

N/S or Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) 6(EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type E/W Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Blr. Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm 

6

Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler No. 4 Cell 11/18/98 66,224 128,769 245.3 34.07 33 0.134 As methane 25 0.100 208 As methane 101 25.7 0.105 9.03 As Methane 1.12 0.005 8.63 70

Boiler No. 4 Cell 11/18/98 64,544 121,846 231.5 32.15 23 0.097 As methane 17 0.073 147 As methane 70 17.8 0.077 7.50 As Methane 0.91 0.004 8.29 65

Boiler No. 4 Cell 11/18/98 66,310 124,615 237.1 32.93 47 0.198 As methane 35 0.148 296 As methane 148 36.7 0.155 13.09 As Methane 1.62 0.007 8.96 75

Boiler No. 4 Cell 11/10/99 47,279 135,000 259.0 35.97 13 0.051 As methane 10 0.038 120 As methane 66 10.6 0.041 8.44 As Methane 0.75 0.003 9.98 91

Boiler No. 4 Cell 11/10/99 55,983 138,000 264.6 36.75 12 0.047 As methane 9 0.035 95 As methane 53 9.9 0.037 5.69 As Methane 0.60 0.002 10.17 94

Boiler No. 4 Cell 11/10/99 59,723 133,269 255.4 35.47 18 0.071 As methane 14 0.053 129 As methane 70 14.4 0.056 7.38 As Methane 0.82 0.003 9.93 90

Boiler No. 4 Cell 11/06/00 59,127 135,000 263.4 36.58 101 0.385 As methane 76 0.288 704 As methane 377 77.9 0.296 17.52 As Methane 1.94 0.007 9.76 87

Boiler No. 4 Cell 11/06/00 58,832 136,500 266.4 37.00 71 0.266 As methane 53 0.199 495 As methane 257 54.5 0.205 12.60 As Methane 1.39 0.005 9.41 81

Boiler No. 4 Cell 11/06/00 59,410 133,500 260.9 36.24 65 0.249 As methane 49 0.186 454 As methane 238 50.4 0.193 15.77 As Methane 1.75 0.007 9.53 83

Boiler No. 4 Cell 11/15/01 59,800 124,500 245.5 34.10 83 0.338 As methane 62 0.253 569 As methane 269 63.6 0.259 13.32 As Methane 1.49 0.006 8.31 65

Boiler No. 4 Cell 11/15/01 58,325 127,500 250.6 34.81 84 0.335 As methane 63 0.251 588 As methane 264 64.1 0.256 12.20 As Methane 1.33 0.005 7.65 57

Boiler No. 4 Cell 11/15/01 57,991 133,500 263.0 36.53 95 0.362 As methane 71 0.271 675 As methane 317 73.1 0.278 17.36 As Methane 1.88 0.007 8.21 64

Boiler No. 4 Cell 11/08/02 61,959 118,500 232.9 32.35 60 0.260 As methane 45 0.195 410 As methane 223 47.5 0.204 18.87 As Methane 2.19 0.009 9.96 92

Boiler No. 4 Cell 11/08/02 62,447 115,500 226.3 31.43 63 0.277 As methane 47 0.207 421 As methane 235 49.1 0.217 19.44 As Methane 2.27 0.010 10.25 98

Boiler No. 4 Cell 11/08/02 64,692 115,500 226.7 31.49 68 0.300 As methane 51 0.225 446 As methane 239 53.9 0.238 24.40 As Methane 2.95 0.013 9.77 90

Boiler No. 4 Cell 11/12/03 57,721 129,600 253.0 35.14 52 0.204 As methane 39 0.153 359 As methane 211 38.8 0.153 0.86 As Methane 0.09 0.0004 10.77 109

Boiler No. 4 Cell 11/12/03 60,409 122,143 238.4 33.11 43 0.180 As methane 32 0.135 285 As methane 155 32.2 0.135 0.63 As Methane 0.07 0.0003 9.96 93

Boiler No. 4 Cell 11/12/03 58,659 133,174 260.9 36.24 109 0.416 As methane 81 0.311 743 As methane 405 81.5 0.312 1.85 As Methane 0.20 0.001 9.96 93

Boiler No. 4 Cell 11/12/04 62,245 98,250 114,923 224.9 31.24 93 0.412 As methane 69 0.308 597 As methane 307 69.5 0.309 1.49 As Methane 0.17 0.001 9.30 82

Boiler No. 4 Cell 11/12/04 67,485 103,443 111,000 217.3 30.18 46 0.214 As methane 35 0.160 277 As methane 170 34.9 0.161 0.71 As Methane 0.09 0.0004 11.20 118

Boiler No. 4 Cell 11/12/04 64,371 101,129 113,538 222.4 30.89 117 0.525 As methane 87 0.393 725 As methane 440 87.3 0.392 0.00 As Methane 0.00 0.000 11.10 116

Boiler No. 4 Cell 12/08/05 57,327 91,941 119,293 234.2 32.53 102 0.435 As methane 76 0.326 951 As methane 489 101.9 0.435 239.34 As Methane 25.65 0.110 9.32 82

Boiler No. 4 Cell 12/08/05 57,589 93,140 120,062 236.1 32.79 148 0.626 As methane 111 0.469 1477 As methane 729 159.1 0.674 449.61 As Methane 48.40 0.205 8.83 75

Boiler No. 4 Cell 12/08/05 59,188 94,048 118,343 233.9 32.49 92 0.390 As methane 69 0.292 1027 As methane 544 113.6 0.486 403.19 As Methane 44.60 0.191 9.65 88

Boiler No. 4 Cell 11/09/06 64,211 105,370 129,631 254.1 35.29 125 0.490 As methane 94 0.367 781 As methane 336 93.8 0.369 2.10 As Methane 0.25 0.001 7.03 52

Boiler No. 4 Cell 11/09/06 60,092 99,597 129,847 254.6 35.36 193 0.760 As methane 145 0.569 1291 As methane 555 145.1 0.570 2.92 As Methane 0.33 0.001 7.04 52

Boiler No. 4 Cell 11/09/06 59,925 98,879 134,262 263.9 36.65 222 0.840 As methane 166 0.629 1560 As methane 641 174.8 0.662 75.91 As Methane 8.50 0.032 6.39 45

Boiler No. 4 Cell 11/16/07 63,860 102,120 114,369 225.6 31.33 97 0.430 As methane 72 0.322 608 As methane 302 72.5 0.322 1.15 As Methane 0.14 0.001 8.91 76

Boiler No. 4 Cell 11/16/07 65,749 107,550 116,184 228.8 31.78 76 0.330 As methane 57 0.247 463 As methane 230 56.9 0.249 0.96 As Methane 0.12 0.001 8.89 75

Boiler No. 4 Cell 11/16/07 64,639 106,353 116,074 229.4 31.86 103 0.450 As methane 77 0.337 709 As methane 339 85.7 0.374 73.53 As Methane 8.88 0.039 8.43 69

Boiler No. 4 Cell 11/21/08 58,103 92,445 132,489 258.0 35.83 160 0.620 As methane 120 0.464 1102 As methane 560 119.8 0.464 2.38 As Methane 0.26 0.001 9.17 80

Boiler No. 4 Cell 11/21/08 57,178 91,989 137,380 268.2 37.25 123 0.460 As methane 92 0.344 863 As methane 436 92.3 0.344 1.90 As Methane 0.20 0.001 9.11 79

Boiler No. 4 Cell 11/21/08 55,460 87,464 132,599 259.5 36.04 75 0.290 As methane 56 0.217 543 As methane 306 56.3 0.217 0.99 As Methane 0.10 0.000 10.34 100

Boiler No. 4 Cell 11/10/09 62,982 102,882 145,480 282.8 39.28 180 0.640 As methane 135 0.479 1148 As methane 567 135.2 0.478 2.75 As Methane 0.32 0.001 8.83 75

Boiler No. 4 Cell 11/10/09 61,079 102,174 149,647 290.7 40.38 157 0.540 As methane 117 0.404 1029 As methane 483 117.6 0.404 2.64 As Methane 0.30 0.001 8.19 66

Boiler No. 4 Cell 11/10/09 58,319 95,787 146,663 282.0 39.17 83 0.290 As methane 62 0.217 569 As methane 299 62.1 0.220 1.27 As Methane 0.14 0.000 9.56 86

Number of Runs 36 18 36 36.00 36.00 36.00 36.00 36.00 36.00 36 36 36.00 36.00 36.00 36.00 36.00 36.00 36.0

n-1 Degrees of Freedom (ν) 35 17 35 35 35 35 35 35 35 35 35 35 35 35 35 35 35 35

MEAN 60,534 98,587 127,450 248.54 34.52 89.71 0.359 67.171 0.269 635 317 71.7 0.287 40.799 4.495 0.019 9.19 80.8

MINIMUM 47,279 87,464 111,000 217.30 30.18 12.43 0.047 9.307 0.035 95 53 9.9 0.037 0.001 0.001 0.000 6.39 44.7

MAXIMUM 67,485 107,550 149,647 290.70 40.38 222.10 0.84 166.30 0.629 1,560 729 175 1 450 48.40 0 11.20 118.19

STD DEVIATION 3,933 5,785 10,060 18.75 2.60 50.35 0.191 37.701 0.143 374 172 41.5 0.162 103.706 11.282 0.048 1.10 17.0

95% CL OF RUNS 68,400 110,157 147,571 286.03 39.73 190.42 0.740 142.574 0.554 1,384 662 154.6 0.611 248.212 27.060 0.115 11.38 114.8

UPL (99% CONFIDENCE) 66,296 107,848 142,187 276 38.33 163.47 0.638 122.40 0.478 1,183 570 132.4 0.524 192.72 21.02 0.089 11 106

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLOsceolaFarms 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Osceola Farms Company

Boiler MACT Database Facility ID: FLOsceolaFarms

THC Emissions Methane Emissions

N/S or Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) 6(EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type E/W Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Blr. Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm 

6

Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

Boiler No. 5 Cell 01/11/99 83,789 136,800 271.6 37.73 3 0.010 As methane 2 0.007 15 As methane 8.7 2.4 0.009 2.10 As Methane 0.33 0.001 10.69 104

Boiler No. 5 Cell 01/11/99 85,415 133,200 264.7 36.76 4 0.015 As methane 3 0.011 21 As methane 12 3.4 0.013 3.19 As Methane 0.51 0.002 10.55 101

Boiler No. 5 Cell 01/11/99 85,420 144,000 286.2 39.75 3 0.012 As methane 2 0.009 19 As methane 11 3.0 0.010 3.84 As Methane 0.61 0.002 10.58 101

Boiler No. 5 Cell 11/08/99 70,012 136,800 270.3 37.54 5 0.017 As methane 3 0.013 29 As methane 17 3.8 0.014 2.68 As Methane 0.35 0.001 10.40 98

Boiler No. 5 Cell 11/08/99 68,970 134,100 265.1 36.83 5 0.018 As methane 4 0.013 33 As methane 19 4.3 0.016 4.67 As Methane 0.60 0.002 10.40 98

Boiler No. 5 Cell 11/08/99 68,976 132,300 260.3 36.16 4 0.015 As methane 3 0.011 27 As methane 15 3.5 0.013 3.94 As Methane 0.51 0.002 10.40 98

Boiler No. 5 Cell 11/02/00 70,403 142,200 280.1 38.90 19 0.069 As methane 15 0.052 116 As methane 61 15.3 0.055 6.07 As Methane 0.80 0.003 9.46 82

Boiler No. 5 Cell 11/02/00 71,399 145,800 286.3 39.76 16 0.054 As methane 12 0.040 95 As methane 49 12.7 0.044 7.57 As Methane 1.01 0.004 9.42 81

Boiler No. 5 Cell 11/02/00 70,812 144,000 282.6 39.25 18 0.065 As methane 14 0.049 111 As methane 59 14.6 0.052 7.46 As Methane 0.99 0.003 9.74 86

Boiler No. 5 Cell 11/13/01 77,655 136,543 269.2 37.38 91 0.349 As methane 68 0.261 501 As methane 222 72.7 0.270 29.82 As Methane 4.33 0.016 7.44 55

Boiler No. 5 Cell 11/13/01 77,270 144,346 285.8 39.69 118 0.417 As methane 89 0.312 643 As methane 279 92.9 0.325 30.21 As Methane 4.36 0.015 7.14 51

Boiler No. 5 Cell 11/13/01 77,195 141,300 278.8 38.72 122 0.440 As methane 91 0.329 656 As methane 286 94.6 0.339 22.98 As Methane 3.32 0.012 7.23 52

Boiler No. 5 Cell 11/06/02 76,968 149,400 293.1 40.70 93 0.312 As methane 69 0.234 507 As methane 270 72.9 0.249 25.21 As Methane 3.63 0.012 9.74 86

Boiler No. 5 Cell 11/06/02 77,621 150,300 295.0 40.97 115 0.401 As methane 86 0.300 631 As methane 340 91.6 0.310 38.89 As Methane 5.64 0.019 9.85 89

Boiler No. 5 Cell 11/06/02 77,994 144,000 282.6 39.25 122 0.430 As methane 91 0.322 667 As methane 377 97.2 0.344 42.21 As Methane 6.15 0.022 10.37 99

Boiler No. 5 Cell 11/18/03 71,314 137,829 273.1 37.93 25 0.092 As methane 19 0.069 144 As methane 74 19.2 0.070 1.53 As Methane 0.20 0.001 9.30 80

Boiler No. 5 Cell 11/18/03 71,754 138,254 274.0 38.06 26 0.097 As methane 20 0.073 148 As methane 80 19.9 0.072 0.34 As Methane 0.05 0.0002 9.90 89

Boiler No. 5 Cell 11/18/03 73,863 137,443 272.3 37.82 21 0.080 As methane 16 0.060 115 As methane 69 15.8 0.058 0.26 As Methane 0.04 0.0001 11.05 111

Boiler No. 5 Cell 11/10/04-11/11/04 79,316 122,448 137,077 273.4 37.97 159 0.581 As methane 119 0.435 1,036 As methane 580 153.7 0.562 235.19 As Methane 34.87 0.128 10.25 95

Boiler No. 5 Cell 11/10/04-11/11/04 78,847 118,052 135,416 268.1 37.24 151 0.564 As methane 113 0.422 1,024 As methane 575 150.9 0.563 258.16 As Methane 38.05 0.142 10.30 96

Boiler No. 5 Cell 11/10/04-11/11/04 76,647 114,337 132,626 262.6 36.47 21 0.081 As methane 16 0.061 111 As methane 64 15.9 0.061 0.24 As Methane 0.03 0.0001 10.50 100

Boiler No. 5 Cell 12/05/05-12/06/05 78,905 121,677 133,257 263.0 36.52 151 0.574 As methane 113 0.430 1,283 As methane 724 189.3 0.720 519.18 As Methane 76.57 0.291 10.35 97

Boiler No. 5 Cell 12/05/05-12/06/05 79,546 122,405 139,366 275.4 38.25 112 0.409 As methane 84 0.306 1,094 As methane 598 162.7 0.591 532.57 As Methane 79.18 0.288 10.00 91

Boiler No. 5 Cell 12/05/05-12/06/05 73,163 111,613 130,445 257.5 35.76 40 0.161 As methane 30 0.121 499 As methane 273 68.3 0.265 279.77 As Methane 38.26 0.149 10.00 91

Boiler No. 5 Cell 11/14/06 76,963 117,736 131,537 260.7 36.21 55 0.210 As methane 41 0.157 290 As methane 146 41.7 0.160 2.18 As Methane 0.31 0.001 9.05 75

Boiler No. 5 Cell 11/14/06 78,532 119,997 133,489 264.9 36.78 45 0.170 As methane 34 0.127 231 As methane 119 33.9 0.128 2.00 As Methane 0.29 0.001 9.36 80

Boiler No. 5 Cell 11/14/06 76,713 117,185 133,374 264.4 36.72 89 0.330 As methane 66 0.247 463 As methane 233 66.4 0.251 0.59 As Methane 0.08 0.0003 9.04 75

Boiler No. 5 Cell 11/27/07-11/28/07 74,096 122,170 135,052 267.5 37.15 98 0.370 As methane 73 0.277 528 As methane 264 73.1 0.273 9.00 75

Boiler No. 5 Cell 11/27/07-11/28/07 73,584 119,081 142,604 282.2 39.19 146 0.520 As methane 109 0.389 796 As methane 377 109.5 0.388 8.31 65

Boiler No. 5 Cell 11/27/07-11/28/07 75,229 122,170 134,916 266.9 37.07 130 0.490 As methane 97 0.367 693 As methane 338 97.5 0.365 8.68 70

Boiler No. 5 Cell 12/03/08 -12/04/08 77,422 124,303 127,878 253.4 35.19 153 0.600 As methane 115 0.449 791 As methane 373 114.5 0.452 8.25 64

Boiler No. 5 Cell 12/03/08 -12/04/08 64,745 118,899 134,708 268.1 37.24 197 0.750 As methane 147 0.562 1,067 As methane 491 129.2 0.482 7.95 61

Boiler No. 5 Cell 12/03/08 -12/04/08 73,848 124,303 127,740 252.6 35.08 220 0.850 As methane 165 0.636 1,215 As methane 547 167.8 0.664 7.65 57

Boiler No. 5 Cell 11/24/09-11/25/09 75,940 127,367 139,557 266.8 37.05 76 0.290 As methane 57 0.217 401 As methane 187 57.0 0.214 0.39 As Methane 0.06 0.0002 8.09 62

Boiler No. 5 Cell 11/24/09-11/25/09 74,194 123,766 144,902 279.1 38.76 98 0.350 As methane 74 0.262 532 As methane 242 73.8 0.265 2.42 As Methane 0.34 0.0012 7.79 59

Boiler No. 5 Cell 11/24/09-11/25/09 74,846 127,367 140,650 273.5 37.99 94 0.350 As methane 71 0.262 509 As methane 241 71.2 0.260 3.88 As Methane 0.54 0.0020 8.33 65

Number of Runs 36 18 36 36.0 36.00 36.00 36.000 36 36 36 36 36 36 30 30 30 36.00 36

n-1 Degrees of Freedom (ν) 35 17 35 35 35 35 35 35 35 35 35 35 35 29 29 29 35 35

MEAN 75,538 120,826 137,867 272.0 37.77 78.99 0.293 59.15 0.219 473 239 67.1 0.248 68.98 10.07 0.037 9.35 82

MINIMUM 64,745 111,613 127,740 252.6 35.08 2.70 0.010 2.02 0.007 15 8.7 2.4 0.009 0.24 0.03 0.000 7.14 51

MAXIMUM 85,420 127,367 150,300 295.0 40.97 219.88 0.850 164.64 0.636 1,283 724 189.3 0.720 532.57 79.18 0.291 11.05 111

STD DEVIATION 4,493 4,150 5,634 10.4 1.44 61.55 0.231 46.09 0.173 383 198 54.8 0.205 145.88 21.46 0.080 1.12 17

95% CL OF RUNS 84,525 129,126 149,134 292.7 40.65 202.10 0.755 151.32 0.565 1,240 636 176.7 0.659 360.75 52.99 0.197 11.58 115

UPL (99% CONFIDENCE) 82,120 127,470 146,120 287 39.88 169.16 0.632 126.66 0.473 1,035 530 147.4 0.549 286.47 42.06 0.157 11 106

Boiler No. 6 Suspension 11/17/04 64,264 100,036 152,143 301.7 41.90 77 0.249 As Methane 57 0.186 1,602 As Methane 788 192.6 0.638 1,125.67 As Methane 135.21 0.448 8.78 72

Boiler No. 6 Suspension 11/17/04 65,197 100,252 152,143 300.8 41.78 26 0.086 As Methane 19 0.064 1,013 As Methane 513 123.5 0.411 854.91 As Methane 104.18 0.346 9.14 77

Boiler No. 6 Suspension 11/17/04 65,965 103,257 156,923 310.3 43.10 55 0.184 As Methane 41 0.138 1,182 As Methane 754 145.8 0.470 846.64 As Methane 104.39 0.336 11.57 122

Boiler No. 6 Suspension 12/13/05 59,657 92,439 141,631 278.8 38.72 34 0.123 As Methane 26 0.092 495 As Methane 243 55.3 0.198 264.60 As Methane 29.51 0.106 8.75 71

Boiler No. 6 Suspension 12/13/05 64,766 98,894 138,460 271.8 37.75 16 0.060 As Methane 12 0.045 240 As Methane 120 29.0 0.107 139.28 As Methane 16.86 0.062 9.01 75

Boiler No. 6 Suspension 12/13/05 57,353 89,868 137,508 269.9 37.49 58 0.216 As Methane 44 0.162 703 As Methane 326 75.3 0.279 296.06 As Methane 31.74 0.118 8.04 62

Boiler No. 6 Suspension 11/16/06-11/17/06 60,978 95,203 146,422 287.5 39.93 27 0.100 As Methane 20 0.075 270 As Methane 126 30.8 0.107 92.83 As Methane 10.58 0.037 8.13 63

Boiler No. 6 Suspension 11/16/06-11/17/06 61,312 96,395 143,778 282.2 39.19 41 0.140 As Methane 30 0.105 395 As Methane 186 45.3 0.160 130.48 As Methane 14.95 0.053 8.22 64

Boiler No. 6 Suspension 11/16/06-11/17/06 62,501 95,527 143,451 281.7 39.13 34 0.120 As Methane 26 0.090 419 As Methane 196 49.0 0.174 199.21 As Methane 23.27 0.083 8.12 63

Number of Runs 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9

n-1 Degrees of Freedom (ν) 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8

MEAN 62,444 96,875 145,829 287.2 39.89 40.94 0.142 30.66 0.106 702 361 83.0 0.283 438.85 52.30 0.177 8.86 74

MINIMUM 57,353 89,868 137,508 269.9 37.49 16.25 0.060 12.17 0.045 240 120 29.0 0.107 92.83 10.58 0.037 8.04 62

MAXIMUM 65,965 103,257 156,923 310.3 43.10 76.58 0.249 57.34 0.186 1,602 788 192.6 0.638 1,125.67 135.21 0.448 11.57 122

STD DEVIATION 2,868 4,181 6,654 14.1 1.96 19.03 0.062 14.25 0.047 468 261 57.7 0.185 391.13 48.03 0.155 1.10 19

95% CL OF RUNS 68,180 105,236 159,136 315.4 43.80 79.00 0.267 59.15 0.200 1,639 884 198.4 0.653 1,221.11 148.36 0.487 11.06 112

UPL (99% CONFIDENCE) 67,982 104,947 158,677 314 43.67 77.68 0.263 58.17 0.197 1,607 866 194.4 0.640 1,194.11 145.05 0.477 11 111

Notes:

lb/hr = pounds per hour.

lb/MMBtu = pounds per million British thermal units.

lb/ton = pounds per ton.

MMBtu/hr = million British thermal units per hour.

TPH = tons per hour.

Footnotes:

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLOsceolaFarms 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Florida - Osceola Farms Company

Boiler MACT Database Facility ID: FLOsceolaFarms

THC Emissions Methane Emissions

N/S or Stack Gas Stack Gas Heat Input Bagasse VOC Emissions as Reported VOC Emissions as Carbon (EPA Method 18/25A) 6(EPA Method 18/25A) Excess

Boiler MACT Data Base Boiler Type E/W Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1

(EPA Method 18/25A) 2(EPA Method 18/25A) 3 As Carbon 5 As Reported 4 As Carbon 

5 Oxygen Air

Combustor ID Common Blr. Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm 

6

Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

As Reported 4

ppm @ 3% O2 as 

Propane

1 Assumed 3,600 Btu/lb average heat content for wet bagasse, except where noted.

2 Based on actual reported data.

3

If reported as propane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as propane x ((3*12.011)/44.09) 

 where 44.09 is the MW of propane and 12.011 is the MW of carbon.

 If reported as methane, it was converted to carbon by the following equation:

 lbs/hr as carbon= lbs/hr as methane x (12.011/16.04) 

 where 16.04 is the MW of methane and 12.011 is the MW of carbon.

4 As reported in test report.

5

If necessary, converted basis to as carbon.

6 THC reported as dry concentration.

Boiler MACT-Sugar IndustryVOC&THC Data-EPA Submission.04.08.10_1.xls, FLOsceolaFarms 4/29/2010, 12:13 PM
Individual Runs - Emission Tests Performed on Bagasse Boilers in Hawaii - Puunene Mill, Hawaii

Boiler MACT Database Facility ID: HIPunneneSugarMill

Boiler MACT Data Base Stack Gas Stack Gas Heat Input Bagasse Excess

Combustor ID Common Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1 Oxygen Air

Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

Boiler 1 and Boiler 2 Suspension 04/17/94 139,629 217,690 561.2 77.94 1,915 Methane 913 1499.72 2.672 8.40 67

Boiler 1 and Boiler 2 Suspension 04/17/94 125,207 195,340 486.7 67.60 683 Methane 328 479.64 0.986 8.50 68

Boiler 1 and Boiler 2 Suspension 04/17/94 135,240 214,538 581.0 80.69 1,503 Methane 705 1140.39 1.963 8.20 64

Boiler 1 and Boiler 2 Suspension 05/19/95 147,240 209,000 404.0 56.11 392 Carbon 192 324.03 0.277 8.72 71

Boiler 1 and Boiler 2 Suspension 05/19/95 158,469 204,000 393.0 54.58 215 Carbon 114 191.42 0.165 9.67 85

Boiler 1 and Boiler 2 Suspension 05/19/95 154,512 202,000 390.0 54.17 274 Carbon 148 237.62 0.213 9.83 88

Boiler 1 and Boiler 2 Suspension 09/23/03 116,192 347.7 48.29 44 Carbon 22 28.35 0.030 9.08 76

Boiler 1 and Boiler 2 Suspension 09/23/03 127,658 361.8 50.25 70 Carbon 35 50.06 0.049 8.89 73

Boiler 1 and Boiler 2 Suspension 09/23/03 125,525 359.1 49.88 137 Carbon 68 96.68 0.093 8.93 74

Number of Runs 9 3 3 9 9 9 9 9 9 9 9

n-1 Degrees of Freedom (ν) 8 2 2 8 8 8 8 8 8 8 8

MEAN 136,630 209,189 205,000 431.6 59.95 581 281 449.8 0.716 8.91 73.98

MINIMUM 116,192 195,340 202,000 347.7 48.29 44 22 28.4 0.030 8.20 63.99

MAXIMUM 158,469 217,690 209,000 581.0 80.69 1,915 913 1,499.7 2.672 9.83 87.89

STD DEVIATION 14,458 12,097 3,606 89.0 12.35 675 318 520.8 0.969 0.55 8.11

95% CL OF RUNS 165,546 233,383 212,211 609.5 84.66 1,932 916 1,491.4 2.654 10.01 90.20

GEOMETRIC MEAN 135,956 208,951 204,979 424.1 58.90 299 149 227.9 0.267 8.90 73.60

UPL (99% CONFIDENCE) 1,886 894 1,455.414 2.587

(EPA Method 18/25A)

(EPA Method 18/25A) 2 As Reported 3

THC Emissions Methane Emissions

VOC Emissions as Reported

(EPA Method 18/25A) ppm @ 3% O2 as 

Propane

As Carbon 

4 As Reported 3 As Carbon 4

VOC Emissions as Carbon (EPA Method 18/25A)
Individual Runs - Emission Tests Performed on Bagasse Boilers in Hawaii - Puunene Mill, Hawaii

Boiler MACT Database Facility ID: HIPunneneSugarMill

Boiler MACT Data Base Stack Gas Stack Gas Heat Input Bagasse Excess

Combustor ID Common Boiler Type Test Flow Rate Flow Rate Steam Rate Rate Burning Rate 

1 Oxygen Air

Date (dscfm) (acfm) (lb/hr) (MMBtu/hr) (TPH) lb/hr lb/MMBtu Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu ppm Basis lb/hr lb/MMBtu (%, dry) (%)

(EPA Method 18/25A)

(EPA Method 18/25A) 2 As Reported 3

THC Emissions Methane Emissions

VOC Emissions as Reported

(EPA Method 18/25A) ppm @ 3% O2 as 

Propane

As Carbon 

4 As Reported 3 As Carbon 4

VOC Emissions as Carbon (EPA Method 18/25A)

Boiler 3 Suspension 04/18/94 216,943 302,577 691.1 95.99 54 Methane 32 65.84 0.095 10.90 108

Boiler 3 Suspension 04/18/94 227,396 292,555 685.7 95.24 35 Methane 22 44.90 0.065 11.50 121

Boiler 3 Suspension 04/18/94 216,536 292,345 669.3 92.96 27 Methane 17 32.55 0.049 11.30 116

Boiler 3 Suspension 05/22/95 223,825 264,000 471.0 65.42 29 Carbon 17 36.99 0.025 10.84 107

Boiler 3 Suspension 05/22/95 217,541 263,000 470.0 65.28 26 Carbon 16 31.92 0.023 10.94 109

Boiler 3 Suspension 05/22/95 222,643 264,000 471.0 65.42 23 Carbon 14 28.26 0.020 11.02 110

Boiler 3 Suspension 09/25/03 150,909 537.1 74.60 128 Carbon 65 108.36 0.09 9.18 78

Boiler 3 Suspension 09/25/03 148,221 573.1 79.60 312 Carbon 147 259.58 0.20 8.26 65

Boiler 3 Suspension 09/25/03 151,961 602.6 83.69 85 Carbon 44 72.29 0.06 9.42 81

Number of Runs 9 3 3 9 9 9 9 9 9 9 9

n-1 Degrees of Freedom (ν) 8 2 2 8 8 8 8 8 8 8 8

MEAN 197,331 295,826 263,667 574.5 79.80 80 42 75.63 0.07 10.37 99.33

MINIMUM 148,221 292,345 263,000 470.0 65.28 23 14 28.26 0.02 8.26 64.76

MAXIMUM 227,396 302,577 264,000 691.1 95.99 312 147 259.58 0.20 11.50 120.87

STD DEVIATION 35,415 5,848 577 93.2 12.94 94 43 73.71 0.06 1.13 19.61

95% CL OF RUNS 268,160 307,521 264,821 760.9 105.69 268 128 223.05 0.18 12.63 138.55

GEOMETRIC MEAN 194,241 295,787 263,666 567.8 78.86 52 30 57.18 0.05 10.32 97.40

UPL (99% CONFIDENCE) 265,715.600 329,079.220 266,949.790 754.502 104.792 261 125 217.962 0.18 12.55 137.19
Attachment 6
From: Amanda Singleton

To: combustionsurvey

Date: 4/9/2010 4:56 PM

Subject: Fwd: Fw: Dow Chemical Sources - Boiler MACT Database

>>> <Eddinger.Jim@epamail.epa.gov> 4/9/2010 4:31 PM >>>

Jim

_______________

James A. Eddinger

Energy Strategies Group

Sector Policies and Programs Division

919-541-5426

----- Forwarded by Jim Eddinger/RTP/USEPA/US on 04/09/2010 04:32 PM

-----

|------------>

| From: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|"Wozniak, Russell (RA)" <wozniara@dow.com> 

|

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| To: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|Jim Eddinger/RTP/USEPA/US@EPA 

|

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| Date: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|04/09/2010 04:28 PM |

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| Subject: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|Dow Chemical Sources - Boiler MACT Database 

|

>------------------------------------------------------------------------------------------------------------------------------------------

|
Jim,

I wanted to pass along to you and others one item that I noticed for

gas-fired process heaters.

The following sources at our Deer Park, TX facility have been shutdown

and should be removed from the data file when EPA makes the next

updates.

The Facility ID is TXROHMHaasDeerPark This is one of the Rohm and

Haas facilities that we acquired in April, 2009.

The Combustor ID's that have been shutdown are:

ACET-2A-1 - ACET-2A-5 - These 5 pre-heaters were shutdown in late 2008.

ACET-2B-1 - ACET-2B-5 - These 5 pre-heaters were shutdown in late 2008.

These sources will not return to operation.

Not sure if these sources were used in the MACT floor calculation, but

they did have relatively low CO levels.

Thanks in advance for forwarding this information, as needed to update

the database.

Please let me know if you have any questions.

Regards,

Russell A. Wozniak

Global Regulatory Affairs

The Dow Chemical Company

Office 361-553-2920

Mobile 361-649-2249
Attachment 7
From: Amanda Singleton

To: combustionsurvey

Date: 4/13/2010 4:18 PM

Subject: Fwd: Boiler/Process Heater MACT Database

Attachments: Furnaces.pdf; EPABoiler MACT Ingleside DB 033010.xls; Plant 2 Furnace EPA 

Report.pdf; Ingleside Boiler MACT test data revision A.xls; Ingleside Boiler MACT test data.xls; Ingleside 

Pasadena Emission Test DB.xls

>>> <Barry_H._Christensen@oxy.com> 4/13/2010 4:12 PM >>>

Folks

We have reviewed your database as revised on 3/3010. With respect to our Ingleside plant (FacilityID: 

TXOccidentalChemGregory) our data is still incorrect. Our Email below of 2/16/10 explained the 

necessary corrections to EPA's database. As stated previously, we have six process furnaces connected 

to two stacks as shown on the enclosed drawing. Plant 1 combines emissions from four process furnaces 

into one stack while Plant 2 combines emissions from two separate process furnaces into another stack. 

Test results were provided to the EPA database based on tests conducted in 1991 for our Plant 1 and 

1997 for Plant 2. We sampled each stack one time with each test having three sample runs, for a total of 

six sample runs on two stacks.

The sheet below is extracted from your database. Using CO as an example, the data is represented for 

our four(4) Plant #1 furnaces in 12 entries as if each furnace was tested separately with a total of 4 

separate stack tests. The testing methodology in actuality measured the contribution of emissions from 

all four furnaces running simultaneously, as measured from the single Plant 1 stack. Therefore, your data, 

marked in yellow does not accurately represent our test results for our Plant 1 furnaces, since no one 

sample number can be assigned to any one furnace (see schematic diagram). This same issue is evident 

for other pollutants.

.

The CO entries in your database for our Plant 2 consist of the average value from three sample runs 

(0.47 ppm @3% O2) from one test done in a 1997. The individual values for CO from the individual 

sample runs for this single test were: 0.45, 0.41, and 0.56 ppm @ 3% O2. Again, the data in the EPA 

database for this source is reflected as if we conducted a separate stack test on each furnace. Also, in 

the case of CO from this test, it is represented as an average of the three runs which is not consistent in 

comparison to the CO data for Plant 1. This may be because you didn't have the individual run values. 

We are enclosing that data from a copy of the pertinent parts of our stack test report. Pls note that several 

sources were included in that report and we only included data from the furnace tests.

In summary, we are unclear on your data management conventions, but are concerned they do not 

accurately reflects our results. Therefore, the sheet below highlights required CO data changes (Plant 1 

in green and Plant 2 in blue) to more accurately reflect our test results, on the assumption that you want 

to include each sample run separately rather than as an average per test.

Also, the data values in blue text are inconsistent with respect to significant figures.

We trust this will help to CORRECT your database and since it is to be used in rulemaking we believe it 

should be accurate.

If you have questions, pls call me at 972 404 3209 or 

(barry_h._christensen@oxy.com<mailto:barry_h._christensen@oxy.com>)

Barry Christensen

Mgr Air Quality
OxyChem

From: combustionsurvey [mailto:combustionsurvey@erg.com]

Sent: Friday, February 26, 2010 1:22 PM

To: Christensen, Barry H.

Subject: Re: Fwd: Boiler/Process Heater MACT Database

Dear Barry,

Thank you for your e-mail. We have been in a holding pattern on addressing data corrections in the

last two weeks to address some analysis. We are looking into these discrepencies and will ensure

that the correct data from your facility gets into our emission database prior to proposal.

Regards,

Combustion Survey Team

>>> Amanda Singleton 2/17/2010 9:07 AM >>>

______________________________________________

From: Christensen, Barry H.

Sent: Tuesday, February 16, 2010 7:01 PM

To: 'Eddinger.Jim@epamail.epa.gov'

Cc: 'Amanda.Singleton@erg.com'

Subject: Boiler/Process Heater MACT Database

Folks,

we have reviewed your database relative to our company, Occidental Chemical Company.

We previously supplied survey and follow-up emission test data. Our Ingleside, TX plant has

two Vinyl Chloride production plants. Our Plant 1 has four furnaces which feed a single stack.

Our Plant 2 has two furnaces which emit through another stack. The NOx CEMS data we

submitted was for a combination of four furnaces (Furnace 1, 2, 3 & 4) from Plant 1 and a

combination of the two furnaces (Furnace 1, 2) from Plant 2 Therefore, the data in your

database appears to duplicate our emissions. This duplicate CEMS and stack test data is

marked with corresponding colors in the enclosed summary from your database. We trust

this will allow correction of this information.

If you have questions, pls call me at 972 404 3209.

Barry Christensen

Mgr Air Quality

OxyChem
Stack SCR

(Catalyst)

Sample Ports

Blower

Stack SCR

(Catalyst)

Sample Ports

Blower

HRB

HRB

Heat Recovery 

Boiler

Heat Recovery 

Boiler
EPA Data for OxyChem as of 03/30/2010 as extracted

Row # Major Source? Classification Data Source SourceTab FacilityID

CombustorID_co

mmon TestID

TestDate

_common Pollutant_Name

Pollutant_

Value 

Numeric

NonDetect?Conversion 

Eq Used

F-Factor 

Equation 

Used

Consolidated

_Std 

Emission 

Value

Consolidat

ed_half 

DL Std 

Emission 

Value

Consolidate

d_Std Value

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control

Control 

Source Fuel

Fuel 

Source

Upstream

/Downstre

am?

25% Fuel 

Cat

10% Fuel 

Cat Fwt

Sample 

Half

Combustor 

Design NG Only?

1 Major Source Boiler ICR Phase I Organic HAP and CO

TXOccidentalChe

mGregory

CTG Duct Burner 

1

Sample 

#1 8/28/1999 CO 0.0024 HI4 FF4 3.24781015

ppm @ 3% 

O2

No 

Equipment

No 

Equipment

No HAP 

APCD 

Control

ET 

Background 

Table

/Hydrogen/

Natural gas/

ET Fuel 

Table Unknown

Gas 1 

(Other) Gas 1 N/A Not RFG

2 Major Source Boiler ICR Phase I

Organic HAP and CO 

(2)

TXOccidentalChe

mGregory

CTG Duct Burner 

2

Sample 

#1 9/1/1999 CO 0.0021 HI4 FF4 2.84183388

ppm @ 3% 

O2

No 

Equipment

No 

Equipment

No HAP 

APCD 

Control

ET 

Background 

Table

/Hydrogen/

Natural gas/

ET Fuel 

Table Unknown

Gas 1 

(Other) Gas 1 N/A Not RFG

3 Major Source Boiler ICR Phase I PM and Metals

TXOccidentalChe

mGregory

CTG Duct Burner 

1

Sample 

#1 8/28/1999

Particulate Matter 

(total, including 

condensibles) ND

Not Able to 

Convert - 

Zero Emission 

Value

Not Able 

to 

Convert - 

Zero 

Emission 

Value

Not Able to 

Convert

No 

Equipment

No 

Equipment

No HAP 

APCD 

Control

ET 

Background 

Table

/Hydrogen/

Natural gas/

ET Fuel 

Table Unknown

Gas 1 

(Other) Gas 1 N/A Not RFG

4 Major Source Boiler ICR Phase I PM and Metals (2)

TXOccidentalChe

mGregory

CTG Duct Burner 

2

Sample 

#1 9/1/1999

Particulate Matter 

(total, including 

condensibles) 0.0006 HI4 FF1 0.0006 lb/MMBtu

No 

Equipment

No 

Equipment

No HAP 

APCD 

Control

ET 

Background 

Table

/Hydrogen/

Natural gas/

ET Fuel 

Table Unknown

Gas 1 

(Other) Gas 1 N/A Not RFG

5 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#1 3/5/1991 CO ND CEq21 FF5 0.05056351 0.025282

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

6 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(4)

TXOccidentalChe

mGregory

VCM Plant 2 

Furnace 1

Sample 

#1 8/1/1997 CO 0.47 CEq21 FF5 0.54962987

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

7 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#2 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

8 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#3 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

9 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#1 3/5/1991 CO ND CEq21 FF5 0.05056351 0.025282

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

10 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(8)

TXOccidentalChe

mGregory

VCM Plant 2 

Furnace 2

Sample 

#1 8/1/1997 CO 0.47 CEq21 FF5 0.54962987

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

11 Major Source Process Heater ICR Phase I PM and Metals (3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#1

10/20/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

12 Major Source Process Heater ICR Phase I PM and Metals (4)

TXOccidentalChe

mGregory

VCM Plant 2 

Furnace 1

Sample 

#1

10/21/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

13 Major Source Process Heater ICR Phase I PM and Metals (5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#1

10/20/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

14 Major Source Process Heater ICR Phase I PM and Metals (6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#1

10/20/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

15 Major Source Process Heater ICR Phase I PM and Metals (7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#1

10/20/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

16 Major Source Process Heater ICR Phase I PM and Metals (8)

TXOccidentalChe

mGregory

VCM Plant 2 

Furnace 2

Sample 

#1

10/21/199

9

Particulate Matter 

(total, including 

condensibles) ND CEq31

Not Able 

to 

Convert - 

No FFactor 

Assigned

Not Able to 

Convert

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

17 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#2 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

18 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#3 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

19 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#1 3/5/1991 CO ND CEq21 FF5 0.05056351 0.025282

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

20 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#2 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

21 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#2 3/5/1991

Total Hydrocarbons 

(THC) 1.1 CEq21 FF5 1.1

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

22 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#3 3/5/1991

Total Hydrocarbons 

(THC) 0.12 CEq21 FF5 0.12

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

23 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#1 3/5/1991

Oxides of Nitrogen 

(NOx) 3.5 CEq21 FF5 3.53944551

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG
Row # Major Source? Classification Data Source SourceTab FacilityID

CombustorID_co

mmon TestID

TestDate

_common Pollutant_Name

Pollutant_

Value 

Numeric

NonDetect?Conversion 

Eq Used

F-Factor 

Equation 

Used

Consolidated

_Std 

Emission 

Value

Consolidat

ed_half 

DL Std 

Emission 

Value

Consolidate

d_Std Value

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control

Control 

Source Fuel

Fuel 

Source

Upstream

/Downstre

am?

25% Fuel 

Cat

10% Fuel 

Cat Fwt

Sample 

Half

Combustor 

Design NG Only?

24 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#2 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

25 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#3 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

26 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#1 3/5/1991

Total Hydrocarbons 

(THC) 1.5 CEq21 FF5 1.51690522

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

27 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#2 3/5/1991

Total Hydrocarbons 

(THC) 1.1 CEq21 FF5 1.1

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

28 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#3 3/5/1991

Total Hydrocarbons 

(THC) 0.12 CEq21 FF5 0.12

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

29 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#3 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

30 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#1 3/5/1991 CO ND CEq21 FF5 0.05056351 0.025282

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

31 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#2 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

32 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(7)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 4

Sample 

#3 3/5/1991 CO ND CEq21 FF5 0.05 0.025

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

33 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#1 3/5/1991

Oxides of Nitrogen 

(NOx) 3.5 CEq21 FF5 3.53944551

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

34 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#2 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

35 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#3 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

36 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#1 3/5/1991

Total Hydrocarbons 

(THC) 1.5 CEq21 FF5 1.51690522

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

37 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#2 3/5/1991

Total Hydrocarbons 

(THC) 1.1 CEq21 FF5 1.1

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

38 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(3)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 1

Sample 

#3 3/5/1991

Total Hydrocarbons 

(THC) 0.12 CEq21 FF5 0.12

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

39 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#1 3/5/1991

Oxides of Nitrogen 

(NOx) 3.5 CEq21 FF5 3.53944551

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

40 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#2 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

41 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#3 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

42 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#1 3/5/1991

Total Hydrocarbons 

(THC) 1.5 CEq21 FF5 1.51690522

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

43 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#2 3/5/1991

Total Hydrocarbons 

(THC) 1.1 CEq21 FF5 1.1

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

44 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(5)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 2

Sample 

#3 3/5/1991

Total Hydrocarbons 

(THC) 0.12 CEq21 FF5 0.12

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

45 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#1 3/5/1991

Oxides of Nitrogen 

(NOx) 3.5 CEq21 FF5 3.53944551

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

46 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#2 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

47 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#3 3/5/1991

Oxides of Nitrogen 

(NOx) 3 CEq21 FF5 3

ppm @ 3% 

O2

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG

48 Major Source Process Heater ICR Phase I

Organic HAP and CO 

(6)

TXOccidentalChe

mGregory

VCM Plant 1 

Furnace 3

Sample 

#1 3/5/1991

Total Hydrocarbons 

(THC) 1.5 CEq21 FF5 1.51690522

ppm @ 3% 

O2 as 

Propane

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

ET 

Background 

Table

/Natural 

gas/

ET Fuel 

Table

Downstre

am

Gas 1 

(NG Only) Gas 1 N/A Not RFG



























Ingleside Emissions Test Database

Major Source? Classification Data Source SourceTab FacilityID

CombustorID_commo

n TestID

TestDate_co

mmon

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (3) TXOccidentalChemGregory

VCM Plant 1 Furnace 

1,2,3,4 Sample #1 3/5/1991

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (5) TXOccidentalChemGregory

VCM Plant 1 Furnace 

1,2,3,4 Sample #2 3/5/1991

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (6) TXOccidentalChemGregory

VCM Plant 1 Furnace 

1,2,3,4 Sample #3 3/5/1991

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (4) TXOccidentalChemGregory

VCM Plant 2 Furnace 

1 & 2 Sample #1 8/1/1997

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (8) TXOccidentalChemGregory

VCM Plant 2 Furnace 

1 & 2 Sample #2 8/1/1997

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (8) TXOccidentalChemGregory

VCM Plant 2 Furnace 

1 & 2 Sample #3 8/1/1997
Avg of 3 test runs

Pollutant_Name Pollutant_Value

Pollutant_Value 

Numeric

NonDetect?Pollutant_

Units

Conversion Eq 

Used

F-Factor 

Equation Used

Consolidated_

Std Emission 

Value

Consolidated_S

td Value

CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

CO 0.45 0.47 ppmvd CEq21 FF5 0.549629871 ppm @ 3% O2

CO 0.41 0.47 ppmvd CEq21 FF5 0.549629871 ppm @ 3% O2

CO 0.56 0.47 
Pollutant_

Method

Pollutant_

Location

Pollutant_

Note

Original 

Combusto

rID_comm

on Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Control Source Fuel

Fuel 

Source

Catalytic 

Reduction 

Catalytic 

Reduction 

APCD 

Control

Background 

Info Table /Natural gas/

ET Fuel 

Table

Catalytic 

Reduction 

Catalytic 

Reduction 

APCD 

Control

Background 

Info Table /Natural gas/

ET Fuel 

Table

Catalytic 

Reduction 

Catalytic 

Reduction 

APCD 

Control

Background 

Info Table /Natural gas/

ET Fuel 

Table

Catalytic 

Reduction 

Catalytic 

Reduction 

APCD 

Control

Background 

Info Table /Natural gas/

ET Fuel 

Table

Catalytic 

Reduction 

Catalytic 

Reduction 

APCD 

Control

Background 

Info Table /Natural gas/

ET Fuel 

Table
Upstream/

Downstrea

m? Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Downstrea

m 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Downstrea

m 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Downstrea

m 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Downstrea

m 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Downstrea

m 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
Total_Soli

ds

Total_Soli

ds_Unit

Total_Soli

ds_Metho

d

Total_Soli

ds_Locati

on

Total_Soli

ds_Note

Dissolved

_Solids

Dissolved

_Solids_U

nit

Dissolved

_Solids_M

ethod

Dissolved

_Solids_L

ocation

Dissolved

_Solids_N

ote

Suspende

d_Solids

Suspende

d_Solids_

Unit

Suspende

d_Solids_

Method
Suspende

d_Solids_

Location

Suspende

d_Solids_

Note

Recirc_Fl

owrate

Recirc_Fl

owrate_U

nit

Recirc_Fl

owrate_M

ethod

Recirc_Fl

owrate_Lo

cation

Recirc_Fl

owrate_N

ote Fwt

Sample 

Half
1 of 30

Ingleside

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/2/2008 1.76 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/3/2008 2.18 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/4/2008 2.22 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/8/2008 1.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/9/2008 1.48 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/15/2008 3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/16/2008 1.38 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/18/2008 1.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/19/2008 1.31 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/21/2008 1.75 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/24/2008 1.47 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/25/2008 1.74 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/28/2008 2.52 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/29/2008 2.65 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/1/2008 41.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/7/2008 38.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/8/2008 36.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/9/2008 42 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/11/2008 38 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/12/2008 33.3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
2 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/13/2008 35.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/15/2008 44.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/18/2008 37.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/20/2008 36.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/25/2008 30.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/27/2008 46 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/28/2008 46.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/30/2008 45.3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/1/2008 1.61 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/5/2008 1.57 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/6/2008 1.45 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/7/2008 1.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/10/2008 1.47 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/11/2008 1.45 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/12/2008 1.32 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/13/2008 2.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/14/2008 2.72 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/17/2008 1.38 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/20/2008 1.41 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/22/2008 1.74 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
3 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/23/2008 1.48 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/26/2008 1.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/27/2008 2.06 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas CO 9/30/2008 2.21 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/2/2008 43.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/3/2008 39.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/4/2008 39.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/5/2008 41.3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/6/2008 41.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/10/2008 39.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/14/2008 41.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/16/2008 33.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/17/2008 39.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/19/2008 37.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/21/2008 38.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/22/2008 37.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/23/2008 35.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/24/2008 31.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/26/2008 37.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 1

Not 

SmallGas NOX 9/29/2008 44.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
4 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/1/2008 1.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/4/2008 1.53 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/5/2008 1.49 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/10/2008 1.49 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/11/2008 1.48 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/12/2008 1.18 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/17/2008 0.97 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/21/2008 1.13 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/25/2008 1.27 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/26/2008 1.38 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/28/2008 1.43 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/29/2008 1.46 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/30/2008 1.52 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/1/2008 40.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/3/2008 41.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/4/2008 41.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/7/2008 39.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/8/2008 38 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/9/2008 40.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/13/2008 37.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
5 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/15/2008 46.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/17/2008 37 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/19/2008 38.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/20/2008 38.4 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/21/2008 37.3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/23/2008 35.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/24/2008 35.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/27/2008 45.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/2/2008 1.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/3/2008 1.53 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/6/2008 1.48 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/7/2008 1.43 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/8/2008 1.42 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/9/2008 1.48 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/13/2008 1.36 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/14/2008 2.29 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/15/2008 1.91 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/16/2008 0.49 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/18/2008 1.32 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/19/2008 1.18 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
6 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/20/2008 0.89 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/22/2008 0.81 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/23/2008 0.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/24/2008 1.03 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas CO 9/27/2008 1.47 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/2/2008 41.1 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/5/2008 42.6 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/6/2008 39.9 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/10/2008 38.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/11/2008 37.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/12/2008 35.7 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/14/2008 45.7 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/16/2008 40.3 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/18/2008 39.2 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/22/2008 36 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/25/2008 34 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/26/2008 38.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/28/2008 43.5 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/29/2008 45 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source Boiler ICR Phase I TXOccidentalChemGregory

CTG Duct 

Burner 2

Not 

SmallGas NOX 9/30/2008 48.8 lbs/hr 15% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
7 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/1/2008 1.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/3/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/4/2008 1.85 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/5/2008 1.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/6/2008 1.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/9/2008 1.88 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/10/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/11/2008 0.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/15/2008 1.29 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/17/2008 1.39 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/18/2008 1.51 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/21/2008 1.2 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/28/2008 1.76 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/30/2008 1.67 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/2/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/7/2008 1.84 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/8/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/12/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
8 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/13/2008 1.15 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/14/2008 1.26 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/16/2008 1.28 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/19/2008 1.32 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/20/2008 1.17 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/22/2008 1.1 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/23/2008 1.13 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/24/2008 1.33 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/25/2008 1.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/26/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/27/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 1

Not 

SmallGas NOX 9/29/2008 1.68 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/2/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/5/2008 1.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/6/2008 1.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/7/2008 1.84 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/11/2008 0.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/12/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/13/2008 1.15 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/14/2008 1.26 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/15/2008 1.29 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
9 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/18/2008 1.51 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/19/2008 1.32 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/20/2008 1.17 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/21/2008 1.2 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/22/2008 1.1 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/23/2008 1.13 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/24/2008 1.33 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/25/2008 1.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/26/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/27/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/29/2008 1.68 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/1/2008 1.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/3/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/4/2008 1.85 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/8/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/9/2008 1.88 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/10/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/16/2008 1.28 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/17/2008 1.39 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/28/2008 1.76 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 2

Not 

SmallGas NOX 9/30/2008 1.67 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
10 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/1/2008 1.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/3/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/4/2008 1.85 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/5/2008 1.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/6/2008 1.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/7/2008 1.84 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/9/2008 1.88 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/10/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/11/2008 0.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/15/2008 1.29 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/18/2008 1.51 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/21/2008 1.2 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/28/2008 1.76 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/30/2008 1.67 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/2/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/8/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/12/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/13/2008 1.15 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/14/2008 1.26 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/16/2008 1.28 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/17/2008 1.39 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
11 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/19/2008 1.32 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/20/2008 1.17 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/22/2008 1.1 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/23/2008 1.13 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/24/2008 1.33 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/25/2008 1.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/26/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/27/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 3

Not 

SmallGas NOX 9/29/2008 1.68 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/2/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/5/2008 1.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/6/2008 1.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/7/2008 1.84 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/11/2008 0.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/12/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/13/2008 1.15 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/14/2008 1.26 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/15/2008 1.29 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/18/2008 1.51 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/19/2008 1.32 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/20/2008 1.17 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
12 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/21/2008 1.2 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/22/2008 1.1 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/23/2008 1.13 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/24/2008 1.33 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/25/2008 1.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/26/2008 1.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/27/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/29/2008 1.68 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/1/2008 1.93 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/3/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/4/2008 1.85 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/8/2008 1.81 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/9/2008 1.88 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/10/2008 1.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/16/2008 1.28 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/17/2008 1.39 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/28/2008 1.76 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 1 

Furnace 4

Not 

SmallGas NOX 9/30/2008 1.67 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/1/2008 0.7 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/2/2008 0.6 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/4/2008 0.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
13 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/7/2008 0.72 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/8/2008 0.46 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/9/2008 0.71 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/10/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/12/2008 0.53 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/13/2008 0.45 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/15/2008 0.87 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/16/2008 0.78 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/17/2008 0.57 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/18/2008 0.52 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/21/2008 0.49 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/22/2008 0.53 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/23/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/25/2008 0.92 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/29/2008 0.96 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/3/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/5/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/6/2008 0.77 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/11/2008 0.5 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/14/2008 0.82 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/19/2008 0.5 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
14 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/20/2008 0.43 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/24/2008 0.74 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/26/2008 0.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/27/2008 0.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/28/2008 0.86 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 1

Not 

SmallGas NOX 9/30/2008 0.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/1/2008 0.7 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/2/2008 0.6 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/3/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/4/2008 0.8 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/6/2008 0.77 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/7/2008 0.72 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/8/2008 0.46 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/9/2008 0.71 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/15/2008 0.87 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/16/2008 0.78 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/17/2008 0.57 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/18/2008 0.52 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/20/2008 0.43 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/21/2008 0.49 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/22/2008 0.53 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
15 of 30

Major Source?

Classificat

ion Data Source FacilityID CombustorID Source Pollutant Date

Emission_

Numerical

Emission_

Unit Correction

F-Factor 

Standardi

zed Value

F-Factor 

Standardi

zed Unit

Conversion 

Eq Used

F-Factor 

Equation 

Used

MaxEmissi

on_Numeri

cal

Max 

Emission

MaxEmiss

ion_Unit

MaxCorre

ction

Max 

Conversion 

Equation Used

F-Factor 

MaxEmiss

ion_Nume

rical

F-Factor 

MaxEmiss

ion_Unit

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/23/2008 0.79 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/27/2008 0.83 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/28/2008 0.86 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/5/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/10/2008 0.69 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/11/2008 0.5 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/12/2008 0.53 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/13/2008 0.45 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/14/2008 0.82 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/19/2008 0.5 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/24/2008 0.74 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/25/2008 0.92 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/26/2008 0.94 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/29/2008 0.96 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value

Major Source

Process 

Heater ICR Phase I TXOccidentalChemGregory

VCM Plant 2 

Furnace 2

Not 

SmallGas NOX 9/30/2008 0.9 lbs/hr 7% O2

Not Able to 

Convert - 

THI Value

Not Able 

to Convert - 

THI Value

Not Able to 

Convert - Max 

Emission 

Value
16 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
17 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
18 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
19 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
20 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
21 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1 Not Able to 

Convert - 

Max 

Emission 

/No 

Equipment/

No 

Equipment

No HAP 

APCD 

Control /Hydrogen/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
22 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

r

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
23 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
24 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
25 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
26 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
27 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
28 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
29 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
30 of 30

F-Factor 

MaxEmissio

n Eq Used

Original 

Combusto

r ID Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Fuel Fuel Source Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

Cat

10% Fuel 

Cat

Heat_Inpu

t Steam

CombUnit

_Op_Indic

ator

CEMS_O

p_Indicato

Not Able to r

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Not Able to Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1

Convert - 

Max 

Emission 

/Selective 

Catalytic 

Reduction 

(SCR)/

Selective 

Catalytic 

Reduction 

(SCR)

No HAP 

APCD 

Control

/Natural 

gas/

CEMS 

Backgrnd 

Table 0 0 0 0 0 0 100 0 0 0 Gas 1 Gas 1
Ingleside Emissions Test Database

Major Source? Classification Data Source SourceTab FacilityID

CombustorID

_common TestID

TestDate_co

mmon Pollutant_Name Pollutant_Value

Pollutant_

Value 

Numeric

NonDetect?Pollutant_

Units

Conversion Eq 

Used

F-Factor 

Equation Used

Consolidated_

Std Emission 

Value

Consolidated_

Std Value

Major Source Boiler ICR Phase I

Organic HAP 

and CO TXOccidentalChemGregory

CTG Duct 

Burner 1 Sample #1 8/28/1999 CO 0.0024 0.0024 lb/mmBtu HI4 FF4 3.247810153 ppm @ 3% O2

Major Source Boiler ICR Phase I

Organic HAP 

and CO (2) TXOccidentalChemGregory

CTG Duct 

Burner 2 Sample #1 9/1/1999 CO 0.0021 0.0021 lb/mmBtu HI4 FF4 2.841833884 ppm @ 3% O2

Major Source Boiler ICR Phase I PM and Metals TXOccidentalChemGregory

CTG Duct 

Burner 1 Sample #1 8/28/1999

Particulate Matter 

(total, including 

condensibles) [0] ND lb/mmBtu

Not Able to 

Convert - Zero 

Emission 

Not Able to 

Convert - Zero 

Emission Value

Not Able to 

Convert

Major Source Boiler ICR Phase I

PM and Metals 

(2) TXOccidentalChemGregory

CTG Duct 

Burner 2 Sample #1 9/1/1999

Particulate Matter 

(total, including 

condensibles) 0.0006 0.0006 lb/mmBtu HI4 FF1 0.0006 lb/MMBtu

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (3) TXOccidentalChemGregory

VCM Plant 1 

Furnace 1 Sample #1 3/5/1991 CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (4) TXOccidentalChemGregory

VCM Plant 2 

Furnace 1 Sample #1 8/1/1997 CO 0.47 0.47 ppmvd CEq21 FF5 0.549629871 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (5) TXOccidentalChemGregory

VCM Plant 1 

Furnace 2 Sample #1 3/5/1991 CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (6) TXOccidentalChemGregory

VCM Plant 1 

Furnace 3 Sample #1 3/5/1991 CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (7) TXOccidentalChemGregory

VCM Plant 1 

Furnace 4 Sample #1 3/5/1991 CO [<0.05] ND

ppm @ 

3% O2 CEq14 FF5 0.05 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

Organic HAP 

and CO (8) TXOccidentalChemGregory

VCM Plant 2 

Furnace 2 Sample #1 8/1/1997 CO 0.47 0.47 ppmvd CEq21 FF5 0.549629871 ppm @ 3% O2

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(3) TXOccidentalChemGregory

VCM Plant 1 

Furnace 1 Sample #1 10/20/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000010] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(4) TXOccidentalChemGregory

VCM Plant 2 

Furnace 1 Sample #1 10/21/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000030] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(5) TXOccidentalChemGregory

VCM Plant 1 

Furnace 2 Sample #1 10/20/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000010] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(6) TXOccidentalChemGregory

VCM Plant 1 

Furnace 3 Sample #1 10/20/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000010] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(7) TXOccidentalChemGregory

VCM Plant 1 

Furnace 4 Sample #1 10/20/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000010] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert

Major Source

Process 

Heater ICR Phase I

PM and Metals 

(8) TXOccidentalChemGregory

VCM Plant 2 

Furnace 2 Sample #1 10/21/1999

Particulate Matter 

(total, including 

condensibles) [<0.0000030] ND lbs./DSCF CEq31

Not Able to 

Convert - No FFactor AssignedNot Able to 

Convert
Pollutant_

Method

Pollutant_

Location

Pollutant_

Note

Original 

Combusto

rID_comm

on Note

Control 

Device

Cleaned 

Control 

Device

Total 

Baseline 

Control Control Source Fuel

Fuel 

Source

Upstream/

Downstre

am? Coal %

Bagasse 

%

Wet 

Biomass 

%

Dry 

Biomass 

%

Heavy 

Liquid %

Light 

Liquid % Gas 1% Gas 2% Other % Waste %

25% Fuel 

No Cat

Equipmen

t

No 

Equipmen

t

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Hydrogen/Natural gas/

ET Fuel 

No Table Unknown 0 0 0 0 0 0 100 0 0 0 Gas 1

Equipmen

t

No 

Equipmen

t

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Hydrogen/Natural gas/

ET Fuel 

No Table Unknown 0 0 0 0 0 0 100 0 0 0 Gas 1

Equipmen

t

No 

Equipmen

t

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Hydrogen/Natural gas/

ET Fuel 

No Table Unknown 0 0 0 0 0 0 100 0 0 0 Gas 1

Equipmen

t

No 

Equipmen

t

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Hydrogen/Natural gas/

ET Fuel 

/Selective Table Unknown 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

/Selective am 0 0 0 0 0 0 100 0 0 0 Gas 1

Catalytic 

Reduction 

Selective 

Catalytic 

Reduction 

No HAP 

APCD 

Control

As Noted in ET 

Background 

Info Table /Natural gas/

ET Fuel 

Table

Downstre

am 0 0 0 0 0 0 100 0 0 0 Gas 1
10% Fuel 

Cat

Total_Soli

ds

Total_Soli

ds_Unit

Total_Soli

ds_Metho

d

Total_Soli

ds_Locati

on

Total_Soli

ds_Note

Dissolved

_Solids

Dissolved

_Solids_U

nit

Dissolved

_Solids_

Method

Dissolved

_Solids_L

ocation

Dissolved

_Solids_N

ote

Suspende

d_Solids

Suspende

d_Solids_

Unit

Suspende

d_Solids_

Method

Suspende

d_Solids_

Location

Suspende

d_Solids_

Note

Recirc_Fl

owrate

Recirc_Fl

owrate_U

nit

Recirc_Fl

owrate_M

ethod

Recirc_Fl

owrate_L

ocation

Recirc_Fl

owrate_N

ote Fwt

Sample 

Half

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1

Gas 1
Attachment 8
combustionsurvey - FTP Folder Uploaded (Revision) 

 

Sir or Madam: 

 

Per instructions in Boiler_Test_Summary.pdf, Section 5.0 Step 5, I am providing notification that we uploaded a folder to the ftp site located 

at ftp://combustionsurvey:combustion@ftp.erg.com. 

 

The folder is named: WY_Sinclair_Sinclair

This submittal is a revision to the data previously submitted. Please see reviewers commentsregarding specific revised content.

 

Data in the folder is associated with the following sources: 

 

 

If there are any questions regarding the folder or files uploaded, please reply to this e-mail. 

 

 

Matthew Poplawski Permitting (Title V, NSR, PSD), EI/GHG, LDAR DFA 

S A G E Environmental Consulting, L.P.

 “Friendly Service, No Surprises!”®

De nv er off i c e 

O: 303-779-0105, x1605

F: 303-779-0106

C: 512-431-6087

s a g e e n v i r o n m e n t a l . c o m

 

From: "Matthew Poplawski" <matthew@sageenvironmental.com>

To: <combustionsurvey@erg.com>

Date: 4/13/2010 9:09 PM

Subject: FTP Folder Uploaded (Revision)

Facility ID

Facility 

Name Address City State

Unit 

ID

Design 

Capacity 

(mmBTU/hr)

Fuel 

Blend

Control 

Device Test Type

WYSinclairWyoming Sinclair 

Wyoming 

Refining 

Company

100 East 

Lincoln 

Highway

Sinclair WY Pt 74 

#2 H2 

Plant 

Heater

288 CO gas

Natural 

gas

Selective 

Catalytic 

Reduction

CO/HC/Formaldehyde/Methane

/PM/HCl/HF/Hg/metal/Dioxins

+NOx/SO2 Stack Test

WYSinclairWyoming Sinclair 

Wyoming 

Refining 

Company

100 East 

Lincoln 

Highway

Sinclair WY Pt 41 

#9 

HPB

100 No. 6 

Residual 

oil

Refinery 

gas

No 

Equipment

CO/HC/Formaldehyde/Methane

/PM/HCl/HF/Hg/metal/Dioxins

+NOx/SO2 Stack Test

Page 1 of 1
Attachment 9
From: <Eddinger.Jim@epamail.epa.gov>

To: combustionsurvey <combustionsurvey@erg.com>

Date: 4/23/2010 12:41 PM

Subject: Fw: Boiler MACT Database

Attachments: Bowater Comparison by parameter (2).xls

Jim

_______________

James A. Eddinger

Energy Strategies Group

Sector Policies and Programs Division

919-541-5426

----- Forwarded by Jim Eddinger/RTP/USEPA/US on 04/23/2010 12:41 PM

-----

|------------>

| From: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

 |Dale.Herendeen@AbitibiBowater.com 

|

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| To: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|Jim Eddinger/RTP/USEPA/US@EPA 

|

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| Cc: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

 |T.Simpkins@westonsolutions.com, Will.Hinson@AbitibiBowater.com, ajain@ncasi.org, 

Brian.Mooney@Abitibibowater.com |

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| Date: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|04/22/2010 02:37 PM |

>------------------------------------------------------------------------------------------------------------------------------------------

|

|------------>

| Subject: |

|------------>

>------------------------------------------------------------------------------------------------------------------------------------------

|

|Boiler MACT Database |
>------------------------------------------------------------------------------------------------------------------------------------------

|

Dear Mr. Eddinger,

We found numerous discrepancies between the uploaded ERT data and the

consolidated database (Weston provided data).

We have attached a spreadsheet illustrating the differences.

If you have any questions, please contact Will Hinson at 803.981.8759.

Thanks,

Dale Herendeen

Environmental Manager

AbitibiBowater -- Catawba Operations

Catawba, South Carolina

803.981.8009

It's OK to print this e-mail. Paper is biodegradable, renewable,

sustainable product made from trees. Growing and harvesting trees

provides jobs for millions of men and women, and working forests are

good for the environment, providing clean air, clean water, habitat and

carbon storage.(See attached file: Bowater Comparison by parameter

(2).xls)
ERT WESTON Report

Combustion Unit ID Dates Tested Pollutant Non Detect Units Emissions Emissions Emissions 

Combination Boiler No. 2 10/8/2009 Total Dioxin/Furans ND ng/dscm @ 7% O2 0.13412 --- 0.319

Combination Boiler No. 2 10/8/2009 Total Dioxin/Furans ND ng/dscm @ 7% O2 0.13412 --- 0.133

Combination Boiler No. 2 10/9/2009 Total Dioxin/Furans ND ng/dscm @ 7% O2 0.13412 --- 0.111

Combination Boiler No. 2 10/6/2009 Antimony (Sb) BDL lb/MMBtu 1.69E-06 8.38E-06 8.38E-06

Combination Boiler No. 2 10/7/2009 Antimony (Sb) BDL lb/MMBtu 1.61E-06 8.31E-06 8.30E-06

Combination Boiler No. 2 10/7/2009 Antimony (Sb) BDL lb/MMBtu 1.47E-06 1.08E-05 1.08E-05

Combination Boiler No. 2 10/6/2009 Arsenic (As) BDL lb/MMBtu 5.81E-06 2.89E-05 2.89E-05

Combination Boiler No. 2 10/7/2009 Arsenic (As) BDL lb/MMBtu 2.25E-06 1.16E-05 1.02E-04

Combination Boiler No. 2 10/7/2009 Arsenic (As) BDL lb/MMBtu 1.23E-06 9.07E-06 9.07E-06

Combination Boiler No. 2 10/6/2009 Beryllium (Be) BDL lb/MMBtu 8.27E-08 4.11E-07 4.11E-07

Combination Boiler No. 2 10/7/2009 Beryllium (Be) BDL lb/MMBtu 7.61E-08 3.92E-07 3.92E-07

Combination Boiler No. 2 10/7/2009 Beryllium (Be) BDL lb/MMBtu 1.86E-07 1.37E-06 1.37E-06

Combination Boiler No. 2 10/6/2009 Cadmium (Cd) BDL lb/MMBtu 4.17E-07 2.08E-06 2.07E-06

Combination Boiler No. 2 10/7/2009 Cadmium (Cd) BDL lb/MMBtu 4.97E-07 2.56E-06 2.56E-06

Combination Boiler No. 2 10/7/2009 Cadmium (Cd) BDL lb/MMBtu 3.83E-07 2.82E-06 2.82E-06

Combination Boiler No. 2 10/6/2009 Chromium (Cr) BDL lb/MMBtu 1.05E-06 5.23E-06 5.23E-06

Combination Boiler No. 2 10/7/2009 Chromium (Cr) BDL lb/MMBtu 8.09E-07 4.16E-06 4.16E-06

Combination Boiler No. 2 10/7/2009 Chromium (Cr) BDL lb/MMBtu 7.32E-07 5.38E-06 5.38E-06

Combination Boiler No. 2 10/6/2009 Cobalt (Co) BDL lb/MMBtu 1.21E-06 6.00E-06 6.00E-06

Combination Boiler No. 2 10/7/2009 Cobalt (Co) BDL lb/MMBtu 1.66E-06 8.54E-06 8.54E-06

Combination Boiler No. 2 10/7/2009 Cobalt (Co) BDL lb/MMBtu 1.63E-06 1.20E-05 1.20E-05

Combination Boiler No. 2 10/6/2009 Lead (Pb) BDL lb/MMBtu 7.32E-06 3.64E-05 3.64E-05

Combination Boiler No. 2 10/7/2009 Lead (Pb) BDL lb/MMBtu 8.22E-06 4.23E-05 4.23E-05

Combination Boiler No. 2 10/7/2009 Lead (Pb) BDL lb/MMBtu 7.13E-06 5.25E-05 5.25E-05

Combination Boiler No. 2 10/6/2009 Manganese (Mn) BDL lb/MMBtu 5.51E-05 2.74E-04 2.74E-04

Combination Boiler No. 2 10/7/2009 Manganese (Mn) BDL lb/MMBtu 7.57E-05 3.90E-04 3.90E-04

Combination Boiler No. 2 10/7/2009 Manganese (Mn) lb/MMBtu 7.36E-05 5.42E-04 5.42E-04

Combination Boiler No. 2 10/6/2009 Mercury (Hg) BDL lb/MMBtu 5.62E-08 2.79E-07 2.79E-07

Combination Boiler No. 2 10/7/2009 Mercury (Hg) BDL lb/MMBtu 7.07E-08 3.64E-07 3.64E-07

Combination Boiler No. 2 10/7/2009 Mercury (Hg) BDL lb/MMBtu 1.25E-07 9.18E-07 9.18E-07

Combination Boiler No. 2 10/6/2009 Nickel (Ni) BDL lb/MMBtu 5.72E-07 2.84E-06 2.84E-06

Combination Boiler No. 2 10/7/2009 Nickel (Ni) BDL lb/MMBtu 6.41E-07 3.30E-06 3.30E-06

Combination Boiler No. 2 10/7/2009 Nickel (Ni) BDL lb/MMBtu 6.50E-07 4.78E-06 4.78E-06

Combination Boiler No. 2 10/6/2009 Phosphorus (P) lb/MMBtu 1.53E-04 7.60E-04 7.59E-04

Combination Boiler No. 2 10/7/2009 Phosphorus (P) lb/MMBtu 1.90E-04 9.78E-04 9.77E-04

Combination Boiler No. 2 10/7/2009 Phosphorus (P) lb/MMBtu 1.93E-04 1.42E-03 1.42E-03

Combination Boiler No. 2 10/6/2009 Selenium (Se) BDL lb/MMBtu 8.27E-07 4.11E-06 4.11E-06

Combination Boiler No. 2 10/7/2009 Selenium (Se) BDL lb/MMBtu 7.61E-07 3.92E-06 3.92E-06

Combination Boiler No. 2 10/7/2009 Selenium (Se) BDL lb/MMBtu 7.45E-07 5.48E-06 5.48E-06

Combination Boiler No. 2 10/6/2009 Hydrogen Chloride (HCl) lb/MMBtu 6.60E-04 3.07E-03 3.07E-03

Combination Boiler No. 2 10/7/2009 Hydrogen Chloride (HCl) lb/MMBtu 9.52E-04 5.27E-03 5.26E-03

Combination Boiler No. 2 10/7/2009 Hydrogen Chloride (HCl) lb/MMBtu 6.41E-04 5.18E-03 5.18E-03

Combination Boiler No. 2 10/6/2009 Hydrogen Fluoride (HF) BDL lb/MMBtu 3.73E-05 1.73E-04 1.73E-04

Combination Boiler No. 2 10/7/2009 Hydrogen Fluoride (HF) BDL lb/MMBtu 3.45E-05 1.91E-04 1.91E-04

Combination Boiler No. 2 10/7/2009 Hydrogen Fluoride (HF) BDL lb/MMBtu 2.69E-05 2.18E-04 2.18E-04

Combination Boiler No. 2 10/6/2009 Particulate Matter (PM2.5) lb/MMBtu 5.67E-03 2.82E-02 2.80E-02

Combination Boiler No. 2 10/7/2009 Particulate Matter (PM2.5) lb/MMBtu 7.44E-03 4.11E-02 4.10E-02

Combination Boiler No. 2 10/7/2009 Particulate Matter (PM2.5) lb/MMBtu 7.06E-03 5.19E-02 5.20E-02

Combination Boiler No. 2 10/6/2009

Condensable Particulate Matter - 

Total lb/MMBtu 3.63E-03 1.80E-02 1.80E-02

Combination Boiler No. 2 10/7/2009

Condensable Particulate Matter - 

Total lb/MMBtu 1.16E-02 2.50E-02 2.50E-02

Combination Boiler No. 2 10/7/2009

Condensable Particulate Matter - 

Total lb/MMBtu 4.57E-03 8.50E-02 8.50E-02

Combination Boiler No. 2 10/6/2009 Particulate Matter (filterable) lb/MMBtu 1.48E-02 7.36E-02 7.35E-02

Combination Boiler No. 2 10/7/2009 Particulate Matter (filterable) lb/MMBtu 2.03E-02 1.04E-02 1.04E-02

Combination Boiler No. 2 10/7/2009 Particulate Matter (filterable) lb/MMBtu 1.81E-02 1.33E-01 1.33E-01

Combination Boiler No. 2 10/8/2009 Formaldehyde ND ppm @ 7% O2 0.009 --- 0.009

Combination Boiler No. 2 10/8/2009 Formaldehyde ND ppm @ 7% O2 0.0097 --- 0.0097

Combination Boiler No. 2 10/9/2009 Formaldehyde ND ppm @ 7% O2 0.0117 --- 0.0117

Combination Boiler No. 2 10/8/2009 Oxides of Nitrogen (NOx) ppm @ 7% O2 274 273 276

Combination Boiler No. 2 10/8/2009 Oxides of Nitrogen (NOx) ppm @ 7% O2 276 276 278

Combination Boiler No. 2 10/9/2009 Oxides of Nitrogen (NOx) ppm @ 7% O2 248 248 252

Combination Boiler No. 2 10/8/2009 SO2 ppm @ 7% O2 663 663 663

Combination Boiler No. 2 10/8/2009 SO2 ppm @ 7% O2 755 755 755

Combination Boiler No. 2 10/9/2009 SO2 ppm @ 7% O2 832 831 831

Combination Boiler No. 2 10/8/2009 CO ppm @ 7% O2 1912 1910 1912

Combination Boiler No. 2 10/8/2009 CO ppm @ 7% O2 1170 1170 1170

Combination Boiler No. 2 10/9/2009 CO ppm @ 7% O2 3488 3490 3488

Combination Boiler No. 2 10/8/2009 Total Hydrocarbons (THC) ppm @ 7% O2 9.02 9.02 8.91

Combination Boiler No. 2 10/8/2009 Total Hydrocarbons (THC) ppm @ 7% O2 5.10 4.99 4.99

Combination Boiler No. 2 10/9/2009 Total Hydrocarbons (THC) ppm @ 7% O2 30.9 31.1 31.1

Combination Boiler No. 2 10/8/2009 Methane ppm @ 7% O2 18.8 --- 18.8

Combination Boiler No. 2 10/8/2009 Methane ppm @ 7% O2 8.6 --- 8.6

Combination Boiler No. 2 10/9/2009 Methane ppm @ 7% O2 28.9 --- 28.9

EPA Data from Consolidated Database