DAQ-2024-008122

11/1/23, 3:07 PM State of Utah Mail - Northrop Grumman - RACT Analysis Report
https://mail.google.com/mail/u/0/?ik=539c285453&view=pt&search=all&permthid=thread-f:1781396751383802978&simpl=msg-f:17813967513838029…1/2
Ana Williams <[e-mail]>
Northrop Grumman - RACT Analysis Report
2 messages
Megan Neiderhiser <[e-mail]>Wed, Nov 1, 2023 at 2:58 PM
To: "Ana Williams ([e-mail])" <[e-mail]>
Cc: "[e-mail]" <[e-mail]>, "[e-mail]" <[e-mail]>, Ember Chadwick
<[e-mail]>, Eri Ottersburg <[e-mail]>
Dear Ana,
In line with the May 2023 letter to NGSC (Clearfield, UT), attached is the Northrop Grumman RACT analysis to support the
upcoming Serious Ozone SIP. Can you please take a look, confirm receipt, and let us know any information on next steps? We
realize these are not formally due until January 2, 2024.

For background, on May 31, 2023, UDAQ notified Northrop Grumman Systems Corporation (NGSC) that because the Clearfield
facility has a PTE of 69 tpy of VOCs, the facility will become a major source once the area is
reclassified. Therefore, NGSC is required to submit a RACT analysis for all emission units that emit NOx and/or VOCs by January
2, 2024.

Many thanks!

Megan Neiderhiser, PE
Principal
1692734 - Emeryville

D [phone]
M [phone]
[e-mail]
_________________________________
Ramboll
50 West Broadway,
Suite 300
Salt Lake City, UT 84101
USA
https://ramboll.com

Classification: Confidential
NGSC RACT Report_2023.pdf
967K
Ana Williams <[e-mail]>Wed, Nov 1, 2023 at 3:06 PM
To: Megan Neiderhiser <[e-mail]>
11/1/23, 3:07 PM State of Utah Mail - Northrop Grumman - RACT Analysis Report
https://mail.google.com/mail/u/0/?ik=539c285453&view=pt&search=all&permthid=thread-f:1781396751383802978&simpl=msg-f:17813967513838029…2/2
Cc: "[e-mail]" <[e-mail]>, "[e-mail]" <[e-mail]>, Ember Chadwick
<[e-mail]>, Eri Ottersburg <[e-mail]>, Jon Black <[e-mail]>
Hi Megan,
Thank you very much. We've received the submission of Northrop Grumman's RACT analysis for their Clearfield Facility. I will go
through it during the next several weeks and let you know if I have any initial questions, or need additional information before I can
determine completeness for it.
The current next steps will be UDAQ's evaluation of the submitted RACT analysis, and we will contact the facility if we have any
questions or findings during our evaluation process. At that point, we will most likely set up a meeting to go through everything. In
addition to the RACT analysis, we'll be sending out an inventory workbook by the end of the year for major sources to complete and
return, most likely in the 1st quarter of 2024. More information on those inventories and instructions will be available once they're ready
to send out.
Please let me know if you have any questions.
Thank you,
Ana Williams | Environmental Engineer | Air Quality Policy Section
Phone: [phone]
Website | Blog | Twitter | Facebook | LinkedIn
[Quoted text hidden]
Confidential
Prepared for
Northrop Grumman Systems Corporation
Prepared by
Ramboll US Consulting, Inc.
Salt Lake City, Utah
San Francisco, California
Project Number
1690032002_Conv
Date
November 2023
RACT ANALYSIS FOR OZONE
NONATTAINMENT
NORTHROP GRUMMAN SYSTEMS CORP.
CLEARFIELD, UTAH

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CONTENTS
1. INTRODUCTION ............................................................................................................. 1
2. FACILITY AND EMISSIONS INFORMATION .................................................................... 2
2.1 Facility Description ......................................................................................................................... 2
2.2 Emissions Profile ............................................................................................................................. 2
3. RACT BACKGROUND ...................................................................................................... 4
3.1 RACT Methodology ......................................................................................................................... 4
3.1.1 Step 1 – Identify All Reasonable Available Control Technologies ............................................. 4
3.1.2 Step 2 – Eliminate Technically Infeasible Options ..................................................................... 4
3.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness ................................ 4
3.1.4 Step 4 – Evaluate Most Effective Controls and Document Results ........................................... 4
3.1.5 Step 5 – Select RACT .................................................................................................................. 5
4. RACT ANALYSIS FOR A NATURAL GAS BOILER .............................................................. 6
4.1 RACT Analysis for NOx Emissions .................................................................................................... 6
4.1.1 Step 1 – Identify All Reasonably Available Control Technologies ............................................. 6
4.1.2 Step 2 – Eliminate Technically Infeasible Options ..................................................................... 6
4.1.3 Steps 3-5 – Select RACT ............................................................................................................. 7
4.2 RACT Analysis for VOC Emissions ................................................................................................... 7
4.2.1 Steps 1-5 – Select RACT ............................................................................................................. 7
5. RACT ANALYSIS FOR NATURAL GAS OVENS .................................................................. 8
5.1 RACT Analysis for NOx Emissions .................................................................................................... 8
5.1.1 Step 1 – Identify All Reasonably Available Control Technologies ............................................. 8
5.1.2 Step 2 – Eliminate Technically Infeasible Options ..................................................................... 8
5.1.3 Steps 3-5 – Select RACT ............................................................................................................. 9
5.2 RACT Analysis for VOC Emissions ................................................................................................... 9
5.2.1 Steps 1-5 – Select RACT ............................................................................................................. 9
6. RACT ANALYSIS FOR NATURAL GAS HOT ROOMS ........................................................ 10
6.1 RACT Analysis for NOx Emissions .................................................................................................. 10
6.1.1 Step 1 – Identify All Reasonably Available Control Technologies ........................................... 10
6.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................... 10
6.1.3 Steps 3-5 – Select RACT ........................................................................................................... 11
6.2 RACT Analysis for VOC Emissions ............................................................................................. 11
6.2.1 Steps 1-5 – Select RACT ........................................................................................................... 11
7. RACT ANALYSIS FOR NATURAL GAS AUTOCLAVES ....................................................... 12

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7.1 RACT Analysis for NOx Emissions .................................................................................................. 12
7.1.1 Step 1 – Identify All Reasonably Available Control Technologies ........................................... 12
7.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................... 12
7.1.3 Steps 3-5 – Select RACT ........................................................................................................... 13
7.2 RACT Analysis for VOC Emissions ............................................................................................. 13
7.2.1 Steps 1-5 – Select RACT ........................................................................................................... 13
8. RACT ANALYSIS FOR VENTILATION ROOMS ................................................................ 14
8.1 RACT Analysis for VOC Emissions ................................................................................................. 14
8.1.1 Step 1 – Identify All Reasonably Available Control Technologies ........................................... 14
8.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................... 14
8.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness .............................. 14
8.1.4 Step 4 – Evaluate Most Effective Controls and Document Results ......................................... 15
8.1.5 Step 5 – Select RACT ................................................................................................................ 15
9. RACT ANALYSIS FOR PAINT/SPRAY BOOTHS .............................................................. 16
9.1 RACT Analysis for NOx Emissions .................................................................................................. 16
9.1.1 Step 1 – Identify All Reasonably Available Control Technologies ........................................... 16
9.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................... 16
9.1.3 Steps 3-5 – Select RACT ........................................................................................................... 16
9.2 RACT Analysis for VOC Emissions ............................................................................................. 17
9.2.1 Step 1 – Identify All Reasonably Available Control Technologies ........................................... 17
9.2.2 Step 2 – Eliminate Technically Infeasible Options ................................................................... 17
9.2.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness .............................. 17
9.2.4 Step 4 – Evaluate Most Effective Controls and Document Results ......................................... 18
9.2.5 Step 5 – Select RACT ................................................................................................................ 18
10. RACT ANALYSIS FOR NATURAL GAS EMERGENCY GENERATORS ................................ 19
10.1 RACT Analysis for NOx Emissions ................................................................................................ 19
10.1.1 Step 1 – Identify All Reasonably Available Control Technologies ......................................... 19
10.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................. 19
10.1.3 Steps 3-5 – Select RACT ......................................................................................................... 19
10.2 RACT Analysis for VOC Emissions ............................................................................................... 20
10.2.1 Step 1 – Identify All Reasonably Available Control Technologies ......................................... 20
10.2.2 Step 2 – Eliminate Technically Infeasible Options ................................................................. 20
10.2.3 Steps 3-5 – Select RACT ......................................................................................................... 20
11. RACT ANALYSIS FOR DIESEL EMERGENCY GENERATORS ........................................... 21

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11.1 RACT Analysis for NOx Emissions ................................................................................................ 21
11.1.1 Step 1 – Identify All Reasonably Available Control Technologies ......................................... 21
11.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................. 21
11.1.3 Steps 3-5 – Select RACT ......................................................................................................... 21
11.2 RACT Analysis for VOC Emissions ............................................................................................... 22
11.2.1 Step 1 – Identify All Reasonably Available Control Technologies ......................................... 22
11.2.2 Step 2 – Eliminate Technically Infeasible Options ................................................................. 22
11.2.3 Steps 3-5 – Select RACT ......................................................................................................... 22
12. RACT ANALYSIS FOR MISC. NATURAL GAS COMBUSTION EQUIPMENT ...................... 23
12.1 RACT Analysis for NOx Emissions ................................................................................................ 23
12.1.1 1 Step 1 – Identify All Reasonably Available Control Technologies.................................... 23
12.1.2 Step 2 – Eliminate Technically Infeasible Options ................................................................. 23
12.1.3 Steps 3-5 – Select RACT ......................................................................................................... 24
12.2 RACT Analysis for VOC Emissions ............................................................................................... 24
12.2.1 Steps 1-5 – Select RACT ......................................................................................................... 24
13. PROPOSED RACT SUMMARY ...................................................................................... 25

TABLES
Table 1: Northrop Grumman Systems RACT Analysis Equipment ................................................... 2
Table 2: Facility-wide PTE ....................................................................................................... 2
Table 3: Facility-wide Actual Emissions ..................................................................................... 3
Table 4: Economic Feasibility Thresholds. .................................................................................. 5
Table 5: Northrop Grumman Systems Proposed RACT for NOx Equipment ...................................... 25
Table 6: Northrop Grumman Systems Proposed RACT for VOC Equipment ..................................... 25
APPENDICES
Appendix A: Cost Effectiveness Analysis
Appendix B: RBLC Data

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ACRONYMS/ABBREVIATIONS
°F – degrees Fahrenheit
ACFM – actual cubic feet per minute
AO – approval order
BACT – Best Available Control Technology
CAA – Clean Air Act
CO – carbon monoxide
DOC – diesel oxidation catalyst
EPA – Environmental Protection Agency
FGR – flue gas recirculation
GCP – good combustion practices
HAP – hazardous air pollutant
HC – hydrocarbons
hr – hour
kW – kilowatt
LAER - Lowest Achievable Emission Rate
LNB – low-NOx burner
MBtu – thousand British thermal units
MMBtu – million British thermal units
NAAQS – National Ambient Air Quality Standards
NOx – oxides of nitrogen
NWF – Northern Wasatch Front
PM – particulate matter
ppmv – parts per million by volume
PTE – potential to emit
RACT – Reasonably Available Control Technology
RBLC – RACT/BACT/LAER Clearinghouse
RTO – regenerative thermal oxidizer
SCR – selective catalytic reduction
SIP – State Implementation Plan

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tpy – tons per year
UDAQ – Utah Division of Air Quality
ULNB – ultra low-NOx burner
VOC – volatile organic compounds
yr – year

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1. INTRODUCTION

On August 3, 2018, the U.S. Environmental Protection Agency (EPA) designated the Northern Wasatch
Front (NWF) as marginal nonattainment for 2015 8-hour ozone National Ambient Air Quality Standards
(NAAQS) standards. The NWF failed to achieve the attainment date of August 3, 2021, and was
reclassified to moderate status on November 7, 2022. The NWF is required to attain the ozone
standard by August 3, 2024, but recent monitoring indicates that it will not attain the standard and
will be reclassified as serious nonattainment status in February 2025. The serious nonattainment
classification will establish new thresholds for major stationary sources. Specifically, as nitrogen oxides
(NOx) and volatile organic compounds (VOCs) are precursors to ozone, the reclassification from
moderate to serious will establish major source potential to emit (PTE) thresholds of 50 tons per year
(tpy) of NOx or VOCs.
Section 110 of the Clean Air Act (CAA) mandates states to develop State Implementation Plans (SIPs)
to outline strategies to achieve and maintain NAAQS. Under the Ozone Implementation Rule in 83
Federal Register (FR) 62998, SIPs must include Reasonably Available Control Technology (RACT) for
all major stationary sources located in nonattainment areas classified as moderate or higher. In
accordance with the Ozone Implementation Rule, the Utah Division of Air Quality (UDAQ) is requiring
all major sources and pending major sources to submit RACT analyses for the control of NOx and VOC
emissions by January 2, 2024.
On May 31, 2023, UDAQ notified Northrop Grumman Systems Corporation (NGSC) that because the
Clearfield facility has a PTE of 69 tpy of VOCs, the facility will become a major source once the area is
reclassified. Therefore, NGSC is required to submit a RACT analysis for all emission units that emit NOx
and/or VOCs by January 2, 2024.
The RACT proposals submitted to UDAQ must include the following:
• A list of each NOx and VOCs emission unit at the facility. All emission units with a potential to
emit either NOx or VOCs must be evaluated.
• A physical description of each emission unit and its operating characteristics.
• Estimates of the potential and actual NOx and VOC emissions from each affected source and
associated supporting documentation.
• The proposed alternative NOx RACT requirement(s) or NOx RACT emissions limitations.
• The proposed alternative VOC RACT requirement(s) or VOC RACT emissions limitations.
• Supporting documentation for the technical and economic considerations for each affected
emission unit.
• A schedule for completing implementation of the RACT requirement or RACT emissions
limitation by May of 2026.
• Proposed testing, monitoring, recordkeeping, and reporting procedures to demonstrate
compliance with the proposed RACT requirement(s) and/or limitations.
• Additional information requested by UDAQ necessary for the evaluation of the RACT analyses.

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2. FACILITY AND EMISSIONS INFORMATION
2.1 Facility Description
NGSC manufactures aerospace composite structures specifically for commercial and defense
contractors at the Clearfield plant located at Freeport Center 14th Street Clearfield, UT 84016. The
manufacturing process includes raw material receiving and storage, material and tool preparation,
fabrication, curing, finishing, testing, and packaging and shipping. The plant is currently a minor
source and operates under the UDAQ Approval Order (AO) DAQE-AN101520028-22.
The following equipment emit or have the potential to emit NOx and/or VOC and are included in this
RACT analysis, see Table 1.
Table 1: Northrop Grumman Systems RACT Analysis Equipment
Equipment NOx VOC
Natural gas boiler Yes Yes
Natural gas ovens Yes Yes
Natural gas hot rooms Yes Yes
Natural gas autoclaves Yes Yes
Ventilation rooms No Yes
Paint/spray booths Yes Yes
Natural gas emergency
generators Yes Yes
Diesel emergency
generators Yes Yes
Miscellaneous natural
gas combustion
equipment
Yes Yes

All correspondence regarding this submission should be addressed to:
Jeff Schmidt
PO Box 160433
Clearfield UT 84016-0433
[phone]
[e-mail]
2.2 Emissions Profile
Based on the current AO, Table 2 shows the total potential emissions from the facility. Note that NGSC
does not calculate all PTE on a source-by-source basis. Estimates of the potential emissions from each
emission unit are given in Appendix A, where available.
Table 2: Facility-wide PTE
NOx VOC
PTE (tpy) 19.49 69.00

Facility-wide actual emissions for NOx and VOC for the 2022 reporting year are presented in Table 3.
Estimates of the actual emissions from each source are not available, as NGSC does not quantify

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actual emissions on a source-by-source basis for all equipment (i.e., all natural gas emissions are
presented together).
Table 3: Facility-wide Actual Emissions 1
NOx VOC
2022 Actual Emissions
(tpy) 7.50 23.68

1 NGSC Internal Air Emissions Summary.

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3. RACT BACKGROUND
3.1 RACT Methodology
As required under CAA 182(b)(2), areas in moderate nonattainment for the 2015 8-hour ozone NAAQS
must implement RACT for existing major sources of VOCs and NOx. When implementing RACT for a
specific facility the U.S. EPA states, “RACT for a particular source is determined on a case-by-case
basis considering the technological and economic circumstances of the individual source.”2
Below are the five steps included in the following RACT analysis.
3.1.1 Step 1 – Identify All Reasonable Available Control Technologies
Identify available control technologies for each emission unit. Methods for identifying potential
technologies include researching the RACT/BACT/LAER Clearinghouse (RBLC) database, surveying
regulatory agencies, conferring with experienced control technology experts, conferring with
equipment vendors, and reviewing available literature including submitted UDAQ RACT reports related
to previous SIP changes.
3.1.2 Step 2 – Eliminate Technically Infeasible Options
Control technologies identified in the previous step are then considered for their technological
feasibility. Determining if a control technology is technically feasible includes evaluation based on
physical, chemical, and engineering principles in addition to demonstration in the field.3 NGSC will only
be considering control equipment that has been demonstrated in practice for sources per the
resources noted in step 1. After reviewing all control technologies, technically infeasible options will be
eliminated from further steps.
3.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness
Any control technologies not eliminated in step 2 are ranked by overall control effectiveness.4 Ranking
based on control effectiveness is not required when all technologies have the same control efficiency
or there is only one option.
3.1.4 Step 4 – Evaluate Most Effective Controls and Document Results
The most effective option is then evaluated based on energy, environmental, and economic impacts. If
a technically feasible control option is eliminated, the next most effective option is evaluated. This
process will continue until the control technology cannot be eliminated by environmental, energy, or
economic impacts.5 UDAQ has published cost thresholds for different levels of emissions reductions for
the purposes of RACT analyses, which are provided in Table 4.6 The high end of these threshold
ranges were utilized in the RACT analysis to determine economic feasibility (i.e., a reduction of 2.50
tpy would have a cost effectiveness threshold of $10,000/ton removed).

2 Federal Register (1979). Vol. 44. No. 181. Proposed Rules – State Implementation Plan; General Preamble for
Proposed Rulemaking on Approval of Plan Revisions for Nonattainment Areas – Supplement (on Control
Techniques Guidelines).
3 U.S. EPA (1990). New Source Review Workshop Manual (Draft): Prevention of Significant Deterioration and
Nonattainment Area Permitting. https://www.epa.gov/sites/default/files/2015-07/documents/1990wman.pdf
4 Ibid.
5 Ibid.
6 UDAQ (2023). DAQ-061-23 Memorandum, Propose for Final Adoption: Amendment to Section R307-110-12;
Incorporation of Utah State Implementation Plan, Section IX.D.11:2015 Ozone NAAQS Northern Wasatch Front
Nonattainment Area.

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Table 4: Economic Feasibility Thresholds.7
Annualized Cost
($/ton removed)
Total Tons
Reduced (tpy)
$0 - $5,000 Any
$5,000 - $10,000 Reduction ≥ 2.00
$10,000 - $15,000 Reduction ≥ 5.00
$15,000 - $20,000 Reduction ≥ 10.00
$20,000 - $25,000 Reduction ≥ 15.00
$25,000 - $30,000 Reduction ≥ 20.00
$30,000 - $35,000 Reduction ≥ 25.00
$35,000 - $40,000 Reduction ≥ 30.00
$40,000+ Case-by-Case
Note: This table is presented in 2023 dollars and is intended to assist in RACT determinations, however additional
discretion is applicable to all final RACT determinations.

3.1.5 Step 5 – Select RACT
The emission rate resulting from the most effective control technology from step 4 is proposed as
RACT for the pollutant and emission unit.8

7 UDAQ (2023). DAQ-061-23 Memorandum, Propose for Final Adoption: Amendment to Section R307-110-12.
8 U.S. EPA (1990). New Source Review Workshop Manual. https://www.epa.gov/sites/default/files/2015-
07/documents/1990wman.pdf

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4. RACT ANALYSIS FOR A NATURAL GAS BOILER
NGSC operates one (1) natural gas-fired boiler with a rated capacity greater than five (5) MMBtu/hr.
The boiler’s rated capacity is 8.37 MMBtu/hr.
4.1 RACT Analysis for NOx Emissions
Typically, NOx is formed from two mechanisms during combustion: thermal NOx and fuel NOx. For
natural gas-fired equipment, fuel NOx is relatively small, so thermal NOx is the main source of NOx
emissions. The formation of thermal NOx can be minimized by controlling the residence time, oxygen
levels, and flame temperature.
4.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas boiler for NOx
reduction are:
• Flue gas recirculation (FGR),
• Selective catalytic reduction (SCR),
• Low-NOx burners (LNB),
• Ultra-low NOx burners (ULNB), and
• Good combustion practices (GCP)
Note, in UDAQ rule R307-316, NOx Emission Controls for Natural-Gas Fired Boilers, all new boilers
greater than 5 MMBtu/hr installed in the Northern Wasatch Front Ozone Non-Attainment Area (Salt
Lake, Davis, Tooele or Weber Counties) shall meet a NOx emission rate of 9 ppmv. While this rule does
not apply to existing boilers, ultra-low NOX burners have been considered as a control option in this
analysis.
4.1.2 Step 2 – Eliminate Technically Infeasible Options
Flue Gas Recirculation (FGR)
FGR is a NOx control technology wherein the exhaust gas is routed into the inlet with the addition of a
forced hot gas fan.9 FGR is most effective for natural gas and low-nitrogen fuels because it lowers the
available oxygen which reduces the formation of NOx. The NOx capture efficiency of FGR is 30-60
percent.10 FGR is considered technically infeasible as add-on controls are not demonstrated in practice
for boilers with firing rates less than 10 MMBtu/hr.
Selective Catalytic Reduction (SCR)
SCR is a method of NOx control that utilizes a catalyst and reagent to reduce NOx emissions. SCR is
typically implemented on stationary source combustion units which require a high level of NOx
reduction.11 Urea is generally used as the reduction reagent. NOx removal efficiencies for SCR are

9 Power Engineering (2003). NOx Control on a Budget: Induced Flue Gas Recirculation. https://www.power-
eng.com/news/nosubx-sub-control-on-a-budget-induced-flue-gas-recirculation/#gref
10 Pollution Online (2000). NOx Emission Reduction Strategies. https://www.pollutiononline.com/doc/nox-
emission-reduction-strategies-0001
11 EPA (2017). Air Pollution Control Cost Manual, Section 4 – Chapter 2.
https://www.epa.gov/sites/default/files/2017-
12/documents/scrcostmanualchapter7thedition_2016revisions2017.pdf

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high, at 90 percent.12 SCR is considered technically infeasible as add-on controls are not
demonstrated in practice for boilers with firing rates less than 10 MMBtu/hr.
Low-NOx Burner (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.13 LNB technology is considered technically
infeasible as add-on controls are not demonstrated in practice for boilers with firing rates less than 10
MMBtu/hr.
Ultra Low-NOx Burner (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.14 ULNB technology has been shown to achieve NOx emissions of 9
ppmv.15 ULNB technology is considered technically infeasible as add-on controls are not demonstrated
in practice for boilers with firing rates less than 10 MMBtu/hr.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing boiler efficiency, and sufficient residence time for complete combustion.
GCP is already proposed to be implemented and is considered the base case.
4.1.3 Steps 3-5 – Select RACT
Based on the information provided in the previous section, the only feasible technology for control of
NOx from the natural gas boiler is GCP. Thus, GCP is proposed as NOx RACT for the natural gas-fired
boiler.
4.2 RACT Analysis for VOC Emissions
4.2.1 Steps 1-5 – Select RACT
NGSC only identified one control method for VOC emissions from natural gas-fired boilers, GCP. None
of the RBLC permitted boilers reviewed were required to employ an add-on control system to reduce
VOC emissions. RACT/BACT for VOCs on natural gas combustion equipment is frequently listed in the
RBLC as “proper operation,” “none,” or “no control,” and there are often notes indicating that no
control technology was technically feasible. GCP for VOC control involves appropriate fuel residence
times, proper fuel-air mixing, and temperature control.
Based on the analysis above, the use of GCP is proposed as VOC RACT for the 8.37 MMBtu/hr natural
gas-fired boiler.

12 EPA. Air Pollution Control Technology Fact Sheet – SCR. https://www3.epa.gov/ttncatc1/dir1/fscr.pdf
13 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf
14 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection
15 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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5. RACT ANALYSIS FOR NATURAL GAS OVENS
NGSC operates thirteen (13) natural gas-fired ovens, with rated capacities ranging from 0.6 MMBtu/hr
to 6.4 MMBtu/hr.
5.1 RACT Analysis for NOx Emissions
5.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas-fired ovens for NOx
reduction are:
• Flue gas recirculation (FGR),
• Low-NOx burners (LNB),
• Ultra-low NOx burners (ULNB), and
• Good combustion practices (GCP).
5.1.2 Step 2 – Eliminate Technically Infeasible Options
Flue Gas Recirculation (FGR)
Flue gas recirculation (FGR) is a NOx control technology wherein the exhaust gas is routed into the
inlet with the addition of a forced hot gas fan.16 FGR is most effective for natural gas and low-nitrogen
fuels because it lowers the available oxygen which reduces the formation of NOx. The NOx capture
efficiency of FGR is 30-60 percent.17 NGSC’s process requires that the ovens are operated at specific
temperatures within tight tolerances throughout the curing process based on specific recipes. The
requirement to hold a cure temperature at a tight tolerance (± 5°F) means that the amount of heat
that is being added needs to be tightly controlled. As a result, FGR is considered technically infeasible
for the natural gas-fired ovens because the flue gas does not have a consistent heat capacity which
would impact the ability to control the temperature within the required tolerances. Additionally, add-
on controls are not demonstrated in practice for natural gas equipment with firing rates less than 10
MMBtu/hr.
Low-NOx Burner (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.18 LNB technology is considered technically
infeasible on the natural gas-fired ovens as add-on controls are not demonstrated in practice for
natural gas equipment with firing rates less than 10 MMBtu/hr.
Ultra Low-NOx Burner (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.19 ULNB technology has been shown to achieve NOx emissions of 9

16 Power Engineering (2003). NOx Control on a Budget: Induced Flue Gas Recirculation. https://www.power-
eng.com/news/nosubx-sub-control-on-a-budget-induced-flue-gas-recirculation/#gref
17 Pollution Online (2000). NOx Emission Reduction Strategies. https://www.pollutiononline.com/doc/nox-
emission-reduction-strategies-0001
18 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf
19 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection

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ppmv.20 ULNB technology is considered technically infeasible on the natural gas-fired ovens as add-on
controls are not demonstrated in practice for natural gas equipment with firing rates less than 10
MMBtu/hr.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
already proposed to be implemented and is considered the base case for the natural gas-fired ovens.
5.1.3 Steps 3-5 – Select RACT
The only feasible technology remaining is GCP. No control efficiency was estimated for GCP. Thus, the
use of GCP is proposed as NOx RACT for the natural gas-fired ovens.
5.2 RACT Analysis for VOC Emissions
5.2.1 Steps 1-5 – Select RACT
As in Section 4.2.1, NGSC only identified one control method for VOC emissions from the natural gas-
fired ovens, GCP.
The use of GCP is proposed as VOC RACT for the natural gas-fired ovens.

20 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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6. RACT ANALYSIS FOR NATURAL GAS HOT ROOMS
NGSC operates seven (7) natural gas-fired hot rooms, with design capacities ranging from 75 MBtu/hr
to 120 MBtu/hr.
6.1 RACT Analysis for NOx Emissions
6.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas hot rooms for NOx
reduction are:
• Flue gas recirculation (FGR),
• Low-NOx burners (LNB),
• Ultra-low NOx burners (ULNB), and
• Good combustion practices (GCP).
6.1.2 Step 2 – Eliminate Technically Infeasible Options
Flue Gas Recirculation (FGR)
Flue gas recirculation (FGR) is a NOx control technology wherein the exhaust gas is routed into the
inlet with the addition of a forced hot gas fan.21 FGR is most effective for natural gas and low-nitrogen
fuels because it lowers the available oxygen which reduces the formation of NOx. The NOx capture
efficiency of FGR is 30-60 percent.22 NGSC’s process requires that the hot rooms are operated at
specific temperatures within tight tolerances throughout the curing process based on specific recipes.
The requirement to hold a cure temperature at a tight tolerance (± 5°) means that the amount of heat
that is being added needs to be tightly controlled. As a result, FGR is considered technically infeasible
for installation on the natural gas-fired hot rooms because the flue gas does not have a consistent
heat capacity which would impact the ability to control the temperature within the required tolerances.
Additionally, add-on controls are not demonstrated in practice for natural gas equipment with firing
rates less than 10 MMBtu/hr.
Low-NOx Burners (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.23 LNB technology is considered technically
infeasible on the natural gas-fired hot rooms as add-on controls are not demonstrated in practice for
natural gas equipment with firing rates less than 10 MMBtu/hr.
Ultra Low-NOx Burners (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.24 ULNB technology has been shown to achieve NOx emissions of 9

21 Power Engineering (2003). NOx Control on a Budget: Induced Flue Gas Recirculation. https://www.power-
eng.com/news/nosubx-sub-control-on-a-budget-induced-flue-gas-recirculation/#gref
22 Pollution Online (2000). NOx Emission Reduction Strategies. https://www.pollutiononline.com/doc/nox-
emission-reduction-strategies-0001
23 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf
24 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection

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ppmv.25 ULNB technology is considered technically infeasible on the natural gas-fired hot rooms as
add-on controls are not demonstrated in practice for natural gas equipment with firing rates less than
10 MMBtu/hr.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the natural gas-fired hot rooms.
6.1.3 Steps 3-5 – Select RACT
The only feasible technology remaining is GCP. No control efficiency was estimated for GCP. Thus, the
use of GCP is proposed as NOx RACT for the natural gas-fired hot rooms.
6.2 RACT Analysis for VOC Emissions
6.2.1 Steps 1-5 – Select RACT
As in Section 4.2.1, NGSC only identified one control method for VOC emissions from the natural gas-
fired hot rooms, GCP.
The use of GCP is proposed to be VOC RACT for natural gas-fired hot rooms.

25 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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7. RACT ANALYSIS FOR NATURAL GAS AUTOCLAVES
NGSC operates eight (8) natural gas-fired autoclaves, with design capacities ranging from 15 Mbtu/hr
to 24.3 MMBtu/hr.
7.1 RACT Analysis for NOx Emissions
7.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas-fired autoclaves
for NOx reduction are:
• Flue gas recirculation (FGR),
• Low-NOx burners (LNB),
• Ultra-low NOx burners (ULNB), and
• Good combustion practices (GCP).
7.1.2 Step 2 – Eliminate Technically Infeasible Options
Flue Gas Recirculation (FGR)
Flue gas recirculation (FGR) is a NOx control technology wherein the exhaust gas is routed into the
inlet with the addition of a forced hot gas fan.26 FGR is most effective for natural gas and low-nitrogen
fuels because it lowers the available oxygen which reduces the formation of NOx. The NOx capture
efficiency of FGR is 30-60 percent.27 NGSC’s process requires that the autoclaves are operated at
specific temperatures within tight tolerances throughout the curing process based on specific recipes.
The requirement to hold a cure temperature at a tight tolerance (± 5°F) means that the amount of
heat that is being added needs to be tightly controlled. As a result, FGR is considered technically
infeasible for installation on the natural gas-fired autoclaves because the flue gas does not have a
consistent heat capacity which would impact the ability to control the temperature within the required
tolerances. Additionally, add-on controls are not demonstrated in practice for natural gas equipment
with firing rates less than 25 MMBtu/hr.
Low-NOx Burner (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.28 LNB technology is considered technically
infeasible on the natural gas-fired autoclaves due to the high turndown ratio required for NGSC’s
processes. Turndown ratio is the ratio between high fire and low fire. LNBs typically have low
turndown ratios, 2:1 or less, while NGSC requires a turndown ratio of at least 33:1 for their
autoclaves.

26 Power Engineering (2003). NOx Control on a Budget: Induced Flue Gas Recirculation. https://www.power-
eng.com/news/nosubx-sub-control-on-a-budget-induced-flue-gas-recirculation/#gref
27 Pollution Online (2000). NOx Emission Reduction Strategies. https://www.pollutiononline.com/doc/nox-
emission-reduction-strategies-0001
28 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf

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Ultra Low-NOx Burner (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.29 ULNB technology has been shown to achieve NOx emissions of 9
ppmv.30 ULNB technology is considered technically infeasible on the natural gas-fired autoclaves due
to the high turndown ratio required for NGSC’s processes. Turndown ratio is the ratio between high
fire and low fire. LNBs typically have low turndown ratios, 2:1 or less, while NGSC requires a turndown
ratio of at least 33:1 for their autoclaves.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the natural gas-fired autoclaves.
7.1.3 Steps 3-5 – Select RACT
The only feasible technology remaining is GCP. No control efficiency was estimated for GCP. Thus, the
use of GCP is proposed as NOx RACT for the natural gas-fired autoclaves.
7.2 RACT Analysis for VOC Emissions
7.2.1 Steps 1-5 – Select RACT
As in Section 4.2.1, NGSC only identified one control method for VOC emissions from the natural gas-
fired autoclaves, GCP.
The use of GCP is proposed to be VOC RACT for natural gas-fired autoclaves.

29 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection
30 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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8. RACT ANALYSIS FOR VENTILATION ROOMS
NGSC operates eleven (11) ventilation rooms, nine (9) of which are mandrel prep rooms. The
ventilation rooms have maximum design capacities ranging from 860 ACFM to 9,400 ACFM. None of
the ventilation rooms emit NOX.
8.1 RACT Analysis for VOC Emissions
8.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the ventilation rooms for VOC
reduction are:
• Regenerative Thermal Oxidizer (RTO),
• Carbon Adsorption System, and
• Compliance with Utah Administrative Code R307-355.
8.1.2 Step 2 – Eliminate Technically Infeasible Options
Regenerative Thermal Oxidizer (RTO)
RTOs are the most common type of thermal oxidizer technology.31 RTOs typically use ceramic direct
contact heat exchangers to achieve temperatures high enough to ignite the waste stream and destroy
VOCs/HAPs.32 RTOs can achieve a VOC destruction efficiency of 99 percent.33 RTO is considered a
technically feasible control for the ventilation rooms.
Carbon Adsorption System
Carbon adsorption generally involves the adsorption of organic compounds on activated carbon.
Adsorption is most effective at lower temperatures and is affected by ambient humidity. Periodic
replacement of the activated carbon is required as buildup of compounds on the filter media will occur.
For VOC concentrations between 500 and 2,000 ppmv, the control efficiency of carbon adsorption can
be 95-99 percent.34 Carbon adsorption is considered a technically feasible control for the ventilation
rooms.
Compliance with Utah Administrative Code R307-355
Compliance with Utah state rule R307-355 regulating the VOC content of coatings for aerospace
vehicles or components standards is considered a technically feasible control for NGSC’s ventilation
rooms.
8.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness
Based on the information provided in the previous section, feasible technologies for control of NOx
from the heated paint booths are the following, with the most effective control first and least effective
control last:
1. RTO (99 percent),
2. Carbon Adsorption System (98 percent), and

31 EPA (2017). Air Pollution Control Cost Manual, Section 3.2, Chapter 2 – Incinerators and Oxidizers.
https://www.epa.gov/sites/default/files/2017-12/documents/oxidizersincinerators_chapter2_7theditionfinal.pdf
32 Ibid.
33 Ibid.
34 EPA (2018). Carbon Adsorbers, Chapter 1. https://www.epa.gov/sites/default/files/2018-
10/documents/final_carbonadsorberschapter_7thedition.pdf

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3. Compliance with Utah Administrative Code R307-355.
No control efficiency was estimated for Compliance with Utah Administrative Code R307-355, since
this is already an applicable requirement for the facility.
8.1.4 Step 4 – Evaluate Most Effective Controls and Document Results
The costs associated with implementing RTO and carbon adsorption for the ventilation rooms were
performed and are summarized in Appendix A Table 1. Compliance with Utah Administrative Code
R307-355 was not costed. RTO was found to have a cost effectiveness of $193,139/ton of VOC which
is above the UDAQ cost effectiveness threshold for >15 tpy of VOC reduction ($25,000/ton of VOC).
Carbon adsorption was found to have a cost effectiveness of $34,872/ton of VOC which is above the
UDAQ cost effectiveness threshold for >15 tpy of VOC reduction ($25,000/ton of VOC). Thus, the
highest ranked option that is economically feasible is compliance with Utah Administrative Code R307-
355.
8.1.5 Step 5 – Select RACT
Based on the RACT analysis performed in steps 1-4, compliance with Utah Administrative Code R307-
355 is proposed as VOC RACT for the ventilation rooms.

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9. RACT ANALYSIS FOR PAINT/SPRAY BOOTHS
NGSC operates twelve (12) paint/spray booths, with design capacities ranging from 11,000 ACFM to
23,000 ACFM. Four paint booths are heated, with firing rates of 750 Mbtu/hr to 950 Mbtu/hr. Six of
the booths are normal spray booths, one is a ceramics spray booth, and the last is a thermal spray
booth.
9.1 RACT Analysis for NOx Emissions
9.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the heated paint booths for NOx
reduction are:
• Low-NOx burners (LNB),
• Ultra Low-NOx burners (ULNB), and
• Good Combustion Practices (GCP).
9.1.2 Step 2 – Eliminate Technically Infeasible Options
Low-NOx Burner (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.35 LNB technology is considered technically
infeasible on the heated paint booths as add-on controls are not demonstrated in practice for natural
gas combustion equipment with firing rates less than 10 MMBtu/hr.
Ultra Low-NOx Burner (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.36 ULNB technology has been shown to achieve NOx emissions of 9
ppmv.37 ULNB technology is considered technically infeasible on the heated paint booths as add-on
controls are not demonstrated in practice for natural gas combustion equipment with firing rates less
than 10 MMBtu/hr.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the heated paint booths.
9.1.3 Steps 3-5 – Select RACT
The only feasible technology remaining is GCP. No control efficiency was estimated for GCP. Thus, the
use of GCP is proposed as NOx RACT for the natural gas-fired autoclaves.

35 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf
36 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection
37 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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9.2 RACT Analysis for VOC Emissions
9.2.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the paint/spray booths for VOC
reduction are:
• Regenerative Thermal Oxidizer (RTO),
• Carbon Adsorption System, and
• Compliance with Utah Administrative Code R307-355.
9.2.2 Step 2 – Eliminate Technically Infeasible Options
Regenerative Thermal Oxidizer (RTO)
RTOs are the most common type of thermal oxidizer technology.38 RTOs typically use ceramic direct
contact heat exchangers to achieve temperatures high enough to ignite the waste stream and destroy
VOCs/HAPs.39 RTOs can achieve a VOC destruction efficiency of 99 percent.40 RTO is considered a
technically feasible control for the paint/spray booths.
Carbon Adsorption System
Carbon adsorption generally involves the adsorption of organic compounds on activated carbon.
Adsorption is most effective at lower temperatures and is affected by ambient humidity. Periodic
replacement of the activated carbon is required as buildup of compounds on the filter media will occur.
For VOC concentrations between 500 and 2,000 ppmv, the control efficiency of carbon adsorption can
be 95-99 percent.41 Carbon adsorption is considered a technically feasible control for the paint/spray
booths.
Compliance with Utah Administrative Code R307-355
Compliance with Utah state rule R307-355 regulating the VOC content of coatings for aerospace
vehicles or components standards is considered a technically feasible control for NGSC’s ventilation
rooms.
9.2.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness
Based on the information provided in the previous section, feasible technologies for control of NOx
from the heated paint booths are the following, with the most effective control first and least effective
control last:
1. RTO (99 percent),
2. Carbon Adsorption System (98 percent), and
3. Compliance with Utah Administrative Code R307-355.
No control efficiency was estimated for Compliance with Utah Administrative Code R307-355.

38 EPA (2017). Air Pollution Control Cost Manual, Section 3.2, Chapter 2 – Incinerators and Oxidizers.
https://www.epa.gov/sites/default/files/2017-12/documents/oxidizersincinerators_chapter2_7theditionfinal.pdf
39 Ibid.
40 Ibid.
41 EPA (2018). Carbon Adsorbers, Chapter 1. https://www.epa.gov/sites/default/files/2018-
10/documents/final_carbonadsorberschapter_7thedition.pdf

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9.2.4 Step 4 – Evaluate Most Effective Controls and Document Results
The costs associated with implementing RTO and carbon adsorption for the paint/spray booths were
performed and are summarized in Appendix A Table 2. Compliance with Utah state rule R307-355 was
not costed. RTO was found to have a cost effectiveness of $415,710/ton of VOC which is above the
UDAQ cost effectiveness threshold for >2 tpy of VOC reduction ($10,000/ton of VOC). Carbon
adsorption was found to have a cost effectiveness of $100,303/ton of VOC which is above the UDAQ
cost effectiveness threshold for >2 tpy of VOC reduction ($10,000/ton of VOC). Thus, compliance with
Utah state rule R307-355 is the only cost-effective control option for the paint/spray booths.
9.2.5 Step 5 – Select RACT
As the RTO and carbon adsorption system were found to be cost ineffective, VOC RACT for the
paint/spray booths is proposed as compliance with Utah state rule R307-355.

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10. RACT ANALYSIS FOR NATURAL GAS EMERGENCY
GENERATORS
NGSC operates eight (8) natural gas-fueled emergency generators with design values ranging from 7 kW
to 240 kW.
10.1 RACT Analysis for NOx Emissions
10.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas-fueled emergency
generators for NOx reduction are:
• Selective catalytic reduction (SCR),
• Use of an engine certified to meet EPA’s New Source Performance Standard (NSPS) for spark-
ignition engines, and
• Good combustion practices (GCP).
10.1.2 Step 2 – Eliminate Technically Infeasible Options
Selective Catalytic Reduction (SCR)
SCR is a method of NOx control which utilizes a catalyst and reagent to reduce NOx emissions. SCR is
typically implemented on stationary source combustion units which require a high level of NOx
reduction.42 Urea is generally used as the reduction reagent. NOx removal efficiencies for SCR are high
at 90 percent.43 SCR is considered technically infeasible for installation on the natural gas-fueled
emergency generators as the operating temperatures required for performance of the SCR catalyst
cannot be achieved during maintenance/testing.
NSPS Certified Engine
NSPS-certified engines rely on combustion controls to comply with EPA Engine NSPS emission
standards. Installation of an NSPS-compliant engine is considered technically feasible for the natural
gas emergency generators.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the natural gas-fueled emergency generators.
10.1.3 Steps 3-5 – Select RACT
NSPS certified engine and GCP are the only remaining control technologies, and NGSC did not
calculate control effectiveness nor cost effectiveness for either of these options. Thus, both NSPS
certified engine and GCP are proposed as NOX RACT for the natural gas-fueled emergency generators.

42 EPA (2017). Air Pollution Control Cost Manual, Section 4 – Chapter 2.
https://www.epa.gov/sites/default/files/2017-
12/documents/scrcostmanualchapter7thedition_2016revisions2017.pdf
43 EPA. Air Pollution Control Technology Fact Sheet – SCR. https://www3.epa.gov/ttncatc1/dir1/fscr.pdf

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10.2 RACT Analysis for VOC Emissions
10.2.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas-fueled emergency
generators for VOC reduction are:
• Use of an engine certified to meet EPA’s New Source Performance Standard (NSPS) for spark-
ignition engines, and
• Good combustion practices (GCP).
10.2.2 Step 2 – Eliminate Technically Infeasible Options
NSPS Certified Engine
NSPS-certified engines rely on combustion controls to comply with EPA Engine NSPS emission
standards. Installation of an NSPS-compliant engine is considered technically feasible for the natural
gas emergency generators.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the natural gas-fueled emergency generators.
10.2.3 Steps 3-5 – Select RACT
NSPS certified engine and GCP are the only remaining control technologies, and NGSC did not
calculate control effectiveness nor cost effectiveness for either of these options. Thus, both NSPS
certified engine and GCP are proposed as VOC RACT for the natural gas-fueled emergency generators.

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11. RACT ANALYSIS FOR DIESEL EMERGENCY
GENERATORS
NGSC operates two (2) diesel-fueled emergency generators with design values of 268 and 225 kW.
11.1 RACT Analysis for NOx Emissions
11.1.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the diesel-fueled emergency
generators for NOx reduction are:
• Selective catalytic reduction (SCR),
• Use of an engine certified to meet EPA’s New Source Performance Standard (NSPS) for spark-
ignition engines, and
• Good combustion practices (GCP).
11.1.2 Step 2 – Eliminate Technically Infeasible Options
Selective Catalytic Reduction (SCR)
SCR is a method of NOx control which utilizes a catalyst and reagent to reduce NOx emissions. SCR is
typically implemented on stationary source combustion units which require a high level of NOx
reduction.44 Urea is generally used as the reduction reagent. NOx removal efficiencies for SCR are high
at 90 percent.45 SCR is considered technically infeasible for installation on the diesel-fueled emergency
generators as normal operating temperatures cannot be achieved during maintenance/testing.
NSPS Certified Engine
NSPS-certified engines rely on combustion to comply with EPA Engine NSPS emission standards. The
diesel-fueled emergency generators already comply with NSPS Subpart IIII, so this is considered
technically feasible.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the diesel-fueled emergency generators.
11.1.3 Steps 3-5 – Select RACT
NSPS certified engine and GCP are the only remaining control technologies, and NGSC did not
calculate control effectiveness nor cost effectiveness for either of these options. Thus, both NSPS
certified engine and GCP are proposed as NOx RACT for the diesel-fueled emergency generators.

44 EPA (2017). Air Pollution Control Cost Manual, Section 4 – Chapter 2.
https://www.epa.gov/sites/default/files/2017-
12/documents/scrcostmanualchapter7thedition_2016revisions2017.pdf
45 EPA. Air Pollution Control Technology Fact Sheet – SCR. https://www3.epa.gov/ttncatc1/dir1/fscr.pdf

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11.2 RACT Analysis for VOC Emissions
11.2.1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the diesel-fueled emergency
generators for VOC reduction are:
• Diesel oxidation catalyst (DOC),
• Use of an engine certified to meet EPA’s New Source Performance Standard (NSPS) for spark-
ignition engines, and
• Good combustion practices (GCP).
11.2.2 Step 2 – Eliminate Technically Infeasible Options
Diesel Oxidation Catalyst (DOC)
DOC is a method of emissions control for diesel combustion equipment. DOCs are catalytic converters
designed specifically for diesel engines and are used to reduce VOC emissions, among other
pollutants. DOC was considered technically infeasible for installation on the diesel-fueled emergency
generators as normal operating temperatures cannot be achieved during maintenance/testing.
NSPS Certified Engine
NSPS-certified engines rely on combustion to comply with EPA Engine NSPS emission standards. The
diesel-fueled emergency generators already comply with NSPS Subpart IIII, so this is considered
technically feasible.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing efficiency, and sufficient residence time for complete combustion. GCP is
considered technically feasible for the diesel-fueled emergency generators.
11.2.3 Steps 3-5 – Select RACT
NSPS certified engine and GCP are the only remaining control technologies, and NGSC did not
calculate control effectiveness nor cost effectiveness for either of these options. Thus, both NSPS
certified engine and GCP are proposed as VOC RACT for the diesel-fueled emergency generators.

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12. RACT ANALYSIS FOR MISC. NATURAL GAS
COMBUSTION EQUIPMENT
NGSC operates seven (7) natural gas boilers that are less than 5 MMBtu/hr. The boilers range from
266 Mbtu/hr to 4.0 MMBtu/hr.
12.1 RACT Analysis for NOx Emissions
12.1.1 1 Step 1 – Identify All Reasonably Available Control Technologies
NGSC identified applicable control technologies using sources including the RBLC database, U.S. EPA
fact sheets, and UDAQ rules. The identified control technologies for the natural gas boiler for NOx
reduction are:
• Flue gas recirculation (FGR),
• Selective catalytic reduction (SCR),
• Low-NOx burners (LNB),
• Ultra-low NOx burners (ULNB), and
• Good combustion practices (GCP)
Note, in May 2023, UDAQ promulgated Rule R307-315, NOx Emission Controls for Natural-Gas Fired
Boilers, new boilers less than 5 MMBtu/hr (greater than 2 MMBtu/hr). Under this rule, new,
reconstructed or modified boilers installed in the Salt Lake, David, Weber, or Tooele Counties shall
meet a NOx emission rate of 9 ppmv. While this rule does not apply to existing boilers, ultra-low NOX
burners have been considered as a control option in this analysis.
12.1.2 Step 2 – Eliminate Technically Infeasible Options
Flue Gas Recirculation (FGR)
FGR is a NOx control technology wherein the exhaust gas is routed into the inlet with the addition of a
forced hot gas fan.46 FGR is most effective for natural gas and low-nitrogen fuels because it lowers the
available oxygen which reduces the formation of NOx. The NOx capture efficiency of FGR is 30-60
percent.47 FGR is considered technically infeasible as add-on controls are not demonstrated in practice
for boilers with firing rates less than 10 MMBtu/hr.
Selective Catalytic Reduction (SCR)
SCR is a method of NOx control that utilizes a catalyst and reagent to reduce NOx emissions. SCR is
typically implemented on stationary source combustion units which require a high level of NOx
reduction.48 Urea is generally used as the reduction reagent. NOx removal efficiencies for SCR are
high, at 90 percent.49 SCR is considered technically infeasible as add-on controls are not
demonstrated in practice for boilers with firing rates less than 10 MMBtu/hr.

46 Power Engineering (2003). NOx Control on a Budget: Induced Flue Gas Recirculation. https://www.power-
eng.com/news/nosubx-sub-control-on-a-budget-induced-flue-gas-recirculation/#gref
47 Pollution Online (2000). NOx Emission Reduction Strategies. https://www.pollutiononline.com/doc/nox-
emission-reduction-strategies-0001
48 EPA (2017). Air Pollution Control Cost Manual, Section 4 – Chapter 2.
https://www.epa.gov/sites/default/files/2017-
12/documents/scrcostmanualchapter7thedition_2016revisions2017.pdf
49 EPA. Air Pollution Control Technology Fact Sheet – SCR. https://www3.epa.gov/ttncatc1/dir1/fscr.pdf

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Low-NOx Burner (LNB)
NOx formation can be reduced through the restriction of oxygen, flame temperature, or residence
time, which is the principle of LNB technology. Staged fuel and staged air burners are both intended to
reduce the formation of thermal NOx. When LNB technology is implemented, emissions of NOx can be
reduced by 50 percent compared to standard burners.50 LNB technology is considered technically
infeasible as add-on controls are not demonstrated in practice for boilers with firing rates less than 10
MMBtu/hr.
Ultra Low-NOx Burner (ULNB)
An ULNB is a type of LNB that can reduce NOx emissions to very low levels, usually below 30 ppmv,
corrected to 3 percent oxygen.51 ULNB technology has been shown to achieve NOx emissions of 9
ppmv.52 ULNB technology is considered technically infeasible as add-on controls are not demonstrated
in practice for boilers with firing rates less than 10 MMBtu/hr.
Good Combustion Practices (GCP)
GCP are a group of several best practices for burners, including proper fuel mixing in the combustion
zone, high temperatures and low oxygen, overall excess oxygen levels high enough to complete
combustion while maximizing boiler efficiency, and sufficient residence time for complete combustion.
GCP is already proposed to be implemented and is considered the base case.
12.1.3 Steps 3-5 – Select RACT
Based on the information provided in the previous section, the only feasible technology for control of
NOx from the natural gas boilers is GCP. Thus, GCP is proposed as NOx RACT for the natural gas-fired
boilers.
12.2 RACT Analysis for VOC Emissions
12.2.1 Steps 1-5 – Select RACT
As in Section 4.2.1, NGSC only identified one control method for VOC emissions from the boilers, GCP.
The use of GCP is proposed to be VOC RACT for the <5 MMBtu/hr boilers.

50 AP-42 Table 1.4-1 – Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas
Combustion. https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf
51 Oak Ridge National Laboratory (2002). Guide to Low-Emission Boiler and Combustion Equipment Selection.
https://www.energy.gov/eere/amo/articles/guide-low-emission-boiler-and-combustion-equipment-selection
52 Power Flame. Nova Low NOx Burners.
https://www.powerflame.com/index.php?option=com_content&view=article&id=110&Itemid=57;

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13. PROPOSED RACT SUMMARY
The proposed RACT for each emission unit are provided in Tables 5 and 6 below. Note that because no
new equipment is required to be installed, an implementation schedule was not provided. Testing
should also not be required, and recordkeeping is already in place at the Facility.
Table 5: Northrop Grumman Systems Proposed RACT for NOx Equipment
Equipment
NOx Ranking of Technically
Feasible Controls
NOx Cost
Effectiveness
($/ton NOx)
NOx Proposed
RACT
Natural gas boiler 1. GCP N/A GCP
Natural gas ovens 1. GCP N/A GCP
Natural gas hot rooms 1. GCP N/A GCP
Natural gas autoclaves 1. GCP N/A GCP
Paint/spray booths 1. GCP N/A GCP
Natural gas emergency
generators
1. GCP
2. NSPS Certified Engine
1. N/A
2. N/A
GCP and NSPS
Certified Engine
Diesel emergency
generators
1. GCP
2. NSPS Certified Engine
1. N/A
2. N/A
GCP and NSPS
Certified Engine
Miscellaneous natural
gas combustion
equipment
1. GCP N/A GCP

Table 6: Northrop Grumman Systems Proposed RACT for VOC Equipment
Equipment
VOC Ranking of Technically
Feasible Controls
VOC Cost
Effectiveness
($/ton VOC)
VOC Proposed
RACT
Natural gas boiler 1. GCP N/A GCP
Natural gas ovens 1. GCP N/A GCP
Natural gas hot rooms 1. GCP N/A GCP
Natural gas autoclaves 1. GCP N/A GCP
Ventilation rooms
1. RTO
2. Carbon Adsorption
3. Compliance with R307-355
1. $193,139
2. $34,872
3. N/A
Compliance with
R307-355
Paint/spray booths
1. RTO
2. Carbon Adsorption
3. Compliance with R307-355
1. $415,710
2. $100,303
3. N/A
Compliance with
R307-355
Natural gas emergency
generators
1. GCP
2. NSPS Certified Engine
1. N/A
2. N/A
GCP and NSPS
Certified Engine
Diesel emergency
generators
1. GCP
2. NSPS Certified Engine
1. N/A
2. N/A
GCP and NSPS
Certified Engine
Miscellaneous natural
gas combustion
equipment
1. GCP N/A GCP

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APPENDIX A
COST EFFECTIVENESS ANALYSIS

Northrop Grumman Systems Corporation
Clearfield, Utah
RACT Analysis
# Table # Table Title Tab Name
1 Table 1 Ventilation/Mandrel Prep Rooms Vent Rooms
2 Table 2 Paint/Spray Booths Paint Booths
1
Table 1
Ventilation/Mandrel Prep Rooms - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Table 1a. Ventilation/Mandrel Prep Room Parameters
Parameter Value Units Notes
Max. Design Capacity 10,250 ACFM
Maximum of all ventilation room design
capacities, provided by NGC.
Stack Diameter 1.0 ft Provided by NGC.
Stack Height 10 ft Provided by NGC.
Exit Gas Temperature 72 Û)Provided by NGC.
Flow Rate 12 ft3/s Provided by NGC.
0.097 g/m3 Calculated from Design Capacity and
VOC Emissions.
6.1E-06 lb/scf Conversion.
22 ppmv
Calculated from VOC flow rate and
Design Capacity.
VOC Molecular Weight 106 lb/lbmol Molecular weight of xylene.1
VOC Flow Rate 0.23 scfm
Calculated from Design Capacity and
VOC Concentration in Exhaust.
3.7 lb/hr Conversion from value in tpy below.
16.3 tpy
80% of annual NGC VOC PTE,
multiplied by the fraction of Max.
Design Capacity (ACFM) to Total
Design Capacity.
Table 1b. Regenerative Thermal Oxidizer (RTO)
Parameter Value Units Description Notes
Qwi 10,250 ACFM Waste gas flow rate --
-Dhc,TEG -17,558 Btu/lb VOC Heat of combustion Heat of combustion of xylene.1
rTEG 55 lb/scf Density of VOC Density of xylene.1
cTEG 22 ppmv Waste gas VOC concentration --
-Dhcw -289 Btu/lb Waste gas heat of combustion
Calculated from VOC heat of combustion, density,
concentration in waste gas, and waste gas density.
rwi 0.074 lb/scf Waste gas density
Assume same as air. EPA Cost Manual Section 3.2
Chapter 2.2
Twi 72 Û)Waste gas inlet temperature --
Tfi 2,000 Û)Combustion temperature EPA Oxidizers Calculation Sheet.3
Tref 77 Û)Reference temperature --
H 0.70 -- Primary heat recovery EPA Cost Manual Section 3.2 Chapter 2.3.2
Tfo 168 Û)Flue gas outlet temperature EPA Cost Manual Section 3.2 Chapter 2.2
Cpm 0.26 %WXOEÛ)Gas heat capacity Assume same as air. EPA Cost Manual Section 3.2
Chapter 2.2
h 1.0% -- Heat loss fraction EPA Cost Manual Section 3.2 Chapter 2, avg. value.2
-Dhaf 21,502 Btu/lb Auxiliary fuel heat of combustion EPA Oxidizers Calculation Sheet.3
raf 0.041 lb/cu ft Auxiliary fuel density EPA Oxidizers Calculation Sheet.3
raf Qaf 11 lb/min Required auxiliary fuel (mass)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Qaf 266 cu ft/min Required auxiliary fuel (volume)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Qtot 10,516 cu ft/min Total gas flowrate
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
-- Btu/hr Natural Gas Use --
delta P 23 psi Pressure drop
EPA Cost Calculator for RTO.3 Default pressure drop
for RTO.
İ 0.60 % Fan Efficiency EPA Cost Calculator for RTO.3 Default fan efficiency.
Powerfan 46 kW
Fan power required to move gas
through incinerator Calculated using EPA Cost Calculator for RTO.3
n10yrRTO Equipment LifeBAAQMD BACT Workbook.4
CRFRTO 0.14 -- Capital Recovery Factor for RTO Calculated using BAAQMD BACT Workbook.4
Interest Rate (i) 7.0 % --
Interest rate for 3rd quarter of 2023, according to
IRS.gov.5
Operator Rate 37 $/hr --
Bureau of Labor Statistics. Hourly mean wage for
Aerospace Engineering and Operations Technologists
and Technicians in Aerospace Product and Parts
Manufacturing in the United States.6
Maintenance Rate 60 $/hr -- Conservatively assumed based on market rates.
1.9 $/therm --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
0.020 $/scf --
Converted from value above using factors of 99,976
Btu/therm and 1,020 Btu/scf.
Cost Information
VOC Emissions
VOC Concentration in Exhaust
Natural Gas Rate
2
Table 1
Ventilation/Mandrel Prep Rooms - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
Electricity Rate 0.15 $/kWh --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
2019 CEPCI Annual Average 608 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
2020 CEPCI Annual Average 596 -- --
Chemical Engineering Plant Cost Index Annual Value
2020.8
2021 CEPCI Annual Average 708 -- --
Chemical Engineering Plant Cost Index Annual Value
2021.8
Basic Equipment Cost (EC) 413,411 $EC = 266400 + 13.98Qtot
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Instrumentation 41,341 $ 0.1 of EC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Sales Tax 28,939 $ 0.07 of EC Avg 7% sales tax in Utah.9
Freight 20,671 $ 0.05 of EC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total PEC 504,362 $
Foundation & Supports 40,349 $ 0.08 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Handling & Erection 70,611 $ 0.14 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Electrical 20,174 $ 0.04 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Piping 10,087 $ 0.02 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Insulation 5,044 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Painting 5,044 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total DI 151,309 $
Site Preparation (SP) 0 $ as required Assumed none required
Building (Bldg) 0 $ as required Assumed none required
Total Direct Cost (DC) 655,670 $DC = PEC + DI + SP + Bldg Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Engineering 50,436 $ 0.10 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Construction and field expenses 25,218 $ 0.05 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Contractor fees 50,436 $ 0.10 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Start-up 10,087 $ 0.02 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Performance test 5,044 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total IC 141,221 $
Contingencies 79,689 $ C = CF(DC + IC)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2 10% Default Contingency Factor Used
Total Capital Investment (TCI) 876,581 $TCI = DC + IC + C Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Operator 20,356 $/yr 0.5 hr per shift
Calculated using EPA Cost Manual Section 3.2 Chapter
2, site data.2
Supervisor 3,053 $/yr 15% of operator costs
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Labor 32,850 $/yr 0.5 hr per shift
Calculated using EPA Cost Manual Section 3.2 Chapter
2, site data.2
Materials 32,850 $/yr 100% of maintenance labor
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Natural gas 2,761,191 $/yr Utah Utility Natural Gas
Electricity 61,212 $/yr Utah Electricity Data
Total DAC 2,911,512 $/yr
Capital Recovery 124,805 $/yr CR = CRF*TCI BAAQMD BACT Workbook.4
Property Tax 8,766 $/yr 0.01 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Insurance 8,766 $/yr 0.01 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
General and Administrative 17,532 $/yr 0.02 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Direct Installation Costs (DI)
Indirect Cost (IC)
Indirect Installation Costs
Maintenance
Utilities
Direct Annual Cost (DAC)
Indirect Annual Cost (IAC)
Labor
Purchased Equipment Cost (PEC)
Direct Capital Cost (DC)
3
Table 1
Ventilation/Mandrel Prep Rooms - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
Overhead 45,008 $/yr 0.80 of Labor Costs BAAQMD BACT Workbook.4
Total IAC 204,876 $/yr --
Total Annualized Cost (TAC) 3,116,388 $/yr TAC = DAC + IAC
Calculated using EPA Cost Manual Section 3.2
Chapter 2.2
Annual VOC emissions 16 tpy --
RTO VOC destruction efficiency 99% %--EPA Air Pollution Control Technology Fact Sheet.4
Annual VOC removed by RTO 16 tpy --
RTO Cost Effectiveness 193,139 $/ton VOC TAC / (VOC & HAP Destroyed) Calculated from TAC and annual VOC removed.
UDAQ Cost Effectiveness Threshold
for VOC 25,000 $/ton VOC --
Utah Air Quality Board Meeting Agenda for
September 12, 2023. Appendix A, Table 1. Cost
threshold for >15 TPY VOC reduction.10
Table 1c. Carbon Adsorption
Parameter Value Units Description Notes
Q 10,250 ft3/min Waste gas flow rate Value given above.
mvoc 3.7 lb/hr VOC inlet rate Value given above.
cvoc 22 ppmv Waste gas VOC concentration Value given above.
Pvoc 3.2E-04 psia Partial pressure of VOC Calculated from Waste Gas VOC Concentration.
kvoc 0.71 -- Empirical parameter
Average value based on range of VOCs in EPA Cost
Calculator for Carbon Adsorbers.11
m0.24--Empirical parameterAverage value based on range of VOCs in EPA Cost
Calculator for Carbon Adsorbers.11
we 0.10 lb VOC/lb
Carbon Equilibrium adsorptivity EPA Cost Calculator for Carbon Adsorber = k x P m .11
wc 0.050 lb VOC/lb
Carbon Working capacity EPA Cost Manual Section 3.1 Chapter 1, Equation
1.15.12
CRR 379 lb/hour Estimated Carbon Replacement Rate
Default value per EPA Cost Calculator for Carbon
Adsorbers.11
8,000
lb
carbon/caniste
r
Carbon Canister Capacity
Based on the sizing for a 4,500 cfm waste gas
flowrate from EPA Cost Calculator for Carbon
Adsorbers: Table B.
11
QA 4,380 hr Time for Adsorption
Default value per EPA Cost Calculator for Carbon
Adsorbers.11
Mc 324,291 lb Estimated Total Carbon Requirement
EPA Cost Calculator for Carbon Adsorbers = (mvoc/wc)
x צA.11
41 # Number of Carbon Canisters Required EPA Cost Calculator for Carbon Adsorbers.11
Tc 328,000 lb Total Carbon Required EPA Cost Calculator for Carbon Adsorbers.11
CC 4.2 $/lb Carbon Cost
EPA Cost Manual Section 3.1 Chapter 1 Carbon
Adsorbers.12
n 5.0 yr Carbon Life
BAAQMD BACT Workbook.4 [i × (1 + i)n] / [(1 + i)n -
1]
CRFcarbon 0.24 -- Capital Recovery Factor (carbon)EPA Cost Manual Section 3.1 Chapter 1.11
n15yrEquipment LifeBAAQMD BACT Workbook.4 [i × (1 + i)n] / [(1 + i)n -
1]
CRFadsorber 0.11 -- Capital Recovery Factor (adsorber)EPA Cost Manual Section 3.1 Chapter 1.12
Interest Rate (i) 7.0 % --
Interest rate for 3rd quarter of 2023, according to
IRS.gov.5
Operator Rate 37 $/hr --
Bureau of Labor Statistics. Hourly mean wage for
Aerospace Engineering and Operations Technologists
and Technicians in Aerospace Product and Parts
Manufacturing in the United States.6
Maintenance Rate 60 $/hr -- Conservatively assumed based on market rates.
1.9 $/therm --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
0.020 $/scf --
Converted from value above using factors of 99,976
Btu/therm and 1,020 Btu/scf.
Electricity 0.15 $/kWh --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
2019 CEPCI Annual Average 608 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
2020 CEPCI Annual Average 596 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
2021 CEPCI Annual Average 708 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
Adsorber vessels and carbon cost 78,376 $EPA Cost Manual Section 3.1 Chapter 1.12
Auxiliary equipment cost 2,000 $EPA Cost Manual Section 3.1 Chapter 1.12
Purchased Equipment Cost (PEC)
Direct Capital Cost (DC)
Cost Effectiveness
Natural Gas
Cost Information
4
Table 1
Ventilation/Mandrel Prep Rooms - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
Total Equipment Cost 80,376 $EC = Absorber + Auxiliary EPA Cost Manual Section 3.1 Chapter 1.12
Instrumentation 8,038 $0.10 of EC EPA Cost Manual Section 3.1 Chapter 1.12
Sales Tax 5,626 $0.07 of EC Avg 7% Sales Tax in Utah.9
Freight 4,019 $0.05 of EC EPA Cost Manual Section 3.1 Chapter 1.12
Total PEC 98,059 $
Foundation & Supports 7,845 $ 0.08 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Handling & Erection 13,728 $ 0.14 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Electrical 3,922 $ 0.04 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Piping 1,961 $ 0.02 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Insulation 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Painting 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Total DI 29,418 $
Site Preparation (SP) 0 $ as required Assumed none required.
Building (Bldg) 0 $ as required Assumed none required.
Total Direct Cost (DC)127,477 $DC = PEC + DI + SP + Bldg EPA Cost Manual Section 3.1 Chapter 1.12
Engineering 9,806 $ 0.10 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Construction and field expenses 4,903 $ 0.05 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Start-up 1,961 $ 0.02 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Performance test 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Total IC 17,651 $
Contractor fees 14,513 $ 0.10(DC + IC)EPA Cost Manual Section 3.1 Chapter 1.12
Contingencies 14,513 $ C = CF(DC + IC)
EPA Cost Manual Section 3.1 Chapter 1.12 10%
Default Contingency Factor Used
Total Capital Investment (TCI)174,153 $TC = DC + IC + C + Contractor EPA Cost Manual Section 3.1 Chapter 1.12
Operator 20,300 $/yr 0.5 hr/shift, 3 shift/day EPA Cost Manual Section 3.1 Chapter 1.12
Supervisor 3,045 $/yr 15% of operator costs EPA Cost Manual Section 3.1 Chapter 1.12
Labor 32,760 $/yr 0.5 hr/shift, 3 shift/day EPA Cost Manual Section 3.1 Chapter 1.12
Materials 32,760 $/yr 100% of maintenance labor EPA Cost Manual Section 3.1 Chapter 1.12
Carbon 383,022 $/yr CRF[CC*Tc*1.14]EPA Cost Manual Section 3.1 Chapter 1.12
Labor 7,848 $/yr CRF[Labor Rate*Tc/CRR]EPA Cost Manual Section 3.1 Chapter 1.12
Total DAC 479,735 $/yr
Capital Recovery 19,121 $/yr CRF*TCI BAAQMD BACT Workbook.4
Property Tax 1,742 $/yr 0.01 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
Insurance 1,742 $/yr 0.01 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
General and Administrative 3,483 $/yr 0.02 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
Overhead 51,162 $/yr 0.80 of Labor Costs BAAQMD BACT Workbook.4
Total IAC 77,250 $/yr
Total Annualized Cost ($/yr) 556,984 $/yr TAC = DAC + IAC
Annual VOC emissions 16 tpy -- Facility estimate.
VOC Control Efficiency 98% -- --EPA Carbon Adsorbers. Chapter 1.13
Annual VOC Removed by Carbon
Adsorber 16 tpy --
Calculated by multiplying Annual VOC Emissions and
VOC Control Efficiency.
Carbon Adsorber Cost Effectiveness 34,872 $/ton VOC --
Calculated from Total Annualized Cost divided by
Annual VOC Removed by Carbon Adsorber.
UDAQ Cost Effectiveness Threshold
for VOC 25,000 $/ton VOC --
Utah Air Quality Board Meeting Agenda for
September 12, 2023. Appendix A, Table 1. Cost
threshold for >15 TPY VOC reduction.10
Notes:
1.
2.
3.
4.
5.
6.
7.
8.
Bureau of Labor Statistics (2022). Hourly Mean Wage for Aerospace Engineering and Operations Technologists and Technicians in Aerospace Product and Parts
Manufacturing in the United States. https://beta.bls.gov/dataViewer/view/timeseries/OEUN000000033640017302103
Chemical Engineering Online (2021). Chemical Engineering Plant Cost Index. https://www.chemengonline.com/pci-home
Direct Installation Costs (DI)
Indirect Cost (IC)
National Center for Biotechnology Information (2023). PubChem Compound Summary for CID 7237, O-Xylene. Retrieved August 25, 2023 from
https://pubchem.ncbi.nlm.nih.gov/compound/O-Xylene.
Bureau of Labor Statistics (2023). Average Energy Prices for the United States, Regions, Census Divisions, and Selected Metropolitan Areas.
https://www.bls.gov/regions/midwest/data/averageenergyprices_selectedareas_table.htm
Indirect Installation Costs
Direct Annual Cost (DAC)
Cost Effectiveness
EPA (2022). EPA Air Pollution Control Cost Manual Incinerators and Oxidizers Calculation Spreadsheet. https://www.epa.gov/system/files/other-files/2022-
09/US%20EPA_OAQPS_IncineratorsOxidizers_Calc_Sheet_september_2022.xlsm
EPA (2017). EPA Air Pollution Control Cost Manual Section 3.2, Chapter 2 - Incinerators and Oxidizers. https://www.epa.gov/sites/default/files/2017-
12/documents/oxidizersincinerators_chapter2_7theditionfinal.pdf
IRS.gov (2023). Interest Rates Remain the Same for the Third Quarter of 2023. https://www.irs.gov/newsroom/interest-rates-remain-the-same-for-the-third-quarter-of-
2023
Indirect Annual Cost (IAC)
Labor
Maintenance
Carbon Replacement
EPA (2003). Air Pollution Control Technology Fact Sheet. https://www3.epa.gov/ttncatc1/dir1/fregen.pdf
5
Table 1
Ventilation/Mandrel Prep Rooms - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
9.
10.
11.
12.
13.
Abbreviations:
ACFM - actual cubic feet per minute hr - hours psi - pounds per square inch
BAAQMD - bay area air quality management district kW - kilowatts psia - actual pounds per square inch
BACT - best achieveable control technology kWh - kilowatt hours RACT - reasonably available control technology
Btu - British thermal unit lb - pounds s - seconds
EPA - environmental protection agency lbmol - pound-moles
scf - standard cubic feet
Û)GHJUHHV)DKUHQKHLW m - meters SCFM - standard cubic feet per minute
ft - feet m
3 - cubic meters tpy - tons per year
ft3/cu ft - cubic feet min - minute VOC - volatile organic compound
g - grams ppmv - parts per million by volume yr - years
EPA (2017). EPA Cost Manual Section 3.1 Chapter 1 - Carbon Adsorbers. https://www.epa.gov/sites/default/files/2018-
10/documents/final_carbonadsorberschapter_7thedition.pdf
EPA (2018). Carbon Adsorbers. Chapter 1. https://www.epa.gov/sites/default/files/2018-10/documents/final_carbonadsorberschapter_7thedition.pdf
EPA (2020). EPA Cost Calculator for Carbon Adsorbers. https://www.epa.gov/sites/default/files/2020-11/epa_carbon_adsorber_calc_sheet_7thedition_nov2020.xlsm
Tax Foundation.org (2023). Utah Tax Rates, Collections, and Burdens.
https://taxfoundation.org/location/utah/#:~:text=How%20does%20Utah's%20tax%20code,tax%20rate%20of%207.19%20percent.
Utah Department of Air Quality (2023). Utah Air Quality Board Meeting Tentative Agenda, Tuesday, September 12, 2023. Appendix A, Table 1.
https://documents.deq.utah.gov/air-quality/board/2023/DAQ-2023-006610.pdf
6
Table 2
Paint/Spray Booths - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Table 2a. Paint/Spray Booth Parameters
Parameter Value Units Notes
Design Capacity 23,000 ACFM
Maximum of all paint/spray booth
design capacities, provided by NGC.
Exit Gas Temperature 72 Û)Provided by NGC.
0.0080 g/m3 Calculated from Design Capacity and
VOC Emissions.
5.0E-07 lb/scf Conversion.
2.17 ppmv
Calculated from VOC flow rate and
Design Capacity.
VOC Molecular Weight 88 lb/lbmol Molecular weight of ethyl acetate.1
VOC Flow Rate 0.050 scfm
Calculated from Design Capacity and
VOC Concentration in Exhaust.
0.69 lb/hr Conversion from value in tpy below.
3.0 tpy
20% of annual NGC VOC PTE,
multiplied by the fraction of Max.
Design Capacity (ACFM) to Total
Design Capacity.
Table 2b. Regenerative Thermal Oxidizer (RTO)
Parameter Value Units Description Notes
Qwi 23,000 ACFM Waste gas flow rate --
-Dhc,TEG -10,923 Btu/lb VOC Heat of combustion Heat of combustion of ethyl acetate.1
rTEG 57 lb/scf Density of VOC Density of ethyl acetate.1
cTEG 2.2 ppmv Waste gas VOC concentration
-Dhcw -18 Btu/lb Waste gas heat of combustion
Calculated from VOC heat of combustion, density,
concentration in waste gas, and waste gas density.
rwi 0.074 lb/scf Waste gas density
Assume same as air. EPA Cost Manual Section 3.2
Chapter 2.2
Twi 72 Û)Waste gas inlet temperature --
Tfi 2,000 Û)Combustion temperature EPA Oxidizers Calculation Sheet.3
Tref 77 Û)Reference temperature --
H 0.70 -- Primary heat recovery EPA Cost Manual Section 3.2 Chapter 2.3.2
Tfo 168 Û)Flue gas outlet temperature EPA Cost Manual Section 3.2 Chapter 2.2
Cpm 0.26 %WXOEÛ)Gas heat capacity Assume same as air. EPA Cost Manual Section 3.2
Chapter 2.2
h 0.010 -- Heat loss fraction EPA Cost Manual Section 3.2 Chapter 2, avg. value.2
-Dhaf 21,502 Btu/lb Auxiliary fuel heat of combustion EPA Oxidizers Calculation Sheet.3
raf 0.041 lb/cu ft Auxiliary fuel density EPA Oxidizers Calculation Sheet.3
raf Qaf 2.90 lb/min Required auxiliary fuel (mass)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Qaf 71 cu ft/min Required auxiliary fuel (volume)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Qtot 23,071 cu ft/min Total gas flowrate
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
delta P 23 psi Pressure drop
EPA Cost Calculator for RTO.3 Default pressure drop
for RTO.
İ 0.60 % Fan Efficiency EPA Cost Calculator for RTO.3 Default fan efficiency.
Powerfan 103 kW
Fan power required to move gas
through incinerator Calculated using EPA Cost Calculator for RTO.3
n10yrRTO Equipment LifeBAAQMD BACT Workbook.4
CRFRTO 0.14 -- Capital Recovery Factor for RTO Calculated using BAAQMD BACT Workbook.4
Interest Rate (i) 7.0 % --
Interest rate for 3rd quarter of 2023, according to
IRS.gov.5
Operator Rate 37 $/hr --
Bureau of Labor Statistics. Hourly mean wage for
Aerospace Engineering and Operations Technologists
and Technicians in Aerospace Product and Parts
Manufacturing in the United States.6
Maintenance Rate 60 $/hr -- Conservatively assumed based on market rates.
1.9 $/therm --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
0.020 $/scf --
Converted from value above using factors of 99,976
Btu/therm and 1,020 Btu/scf.
Electricity Rate 0.15 $/kWh --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
2019 CEPCI Annual Average 608 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
Natural Gas Rate
VOC Concentration in Exhaust
VOC Emissions
Cost Information
7
Table 2
Paint/Spray Booths - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
2020 CEPCI Annual Average 596 -- --
Chemical Engineering Plant Cost Index Annual Value
2020.8
2021 CEPCI Annual Average 708 -- --
Chemical Engineering Plant Cost Index Annual Value
2021.8
Basic Equipment Cost (EC) 588,933 $EC = 266400 + 13.98Qtot
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Instrumentation 58,893 $ 0.1 of EC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Sales Tax 41,225 $ 0.07 of EC Avg 7% sales tax in Utah.9
Freight 29,447 $ 0.05 of EC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total PEC 718,498 $
Foundation & Supports 57,480 $ 0.08 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Handling & Erection 100,590 $ 0.14 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Electrical 28,740 $ 0.04 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Piping 14,370 $ 0.02 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Insulation 7,185 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Painting 7,185 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total DI 215,549 $
Site Preparation (SP) 0 $ as required Assumed none required
Building (Bldg) 0 $ as required Assumed none required
Total Direct Cost (DC) 934,048 $DC = PEC + DI + SP + Bldg Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Engineering 71,850 $ 0.10 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Construction and field expenses 35,925 $ 0.05 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Contractor fees 71,850 $ 0.10 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Start-up 14,370 $ 0.02 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Performance test 7,185 $ 0.01 of PEC
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Total IC 201,180 $
Contingencies 113,523 $ C = CF(DC + IC)
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2 10% Default Contingency Factor Used
Total Capital Investment (TCI) 1,248,750 $TCI = DC + IC + C Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Operator 20,356 $/yr 0.5 hr per shift
Calculated using EPA Cost Manual Section 3.2 Chapter
2, site data.2
Supervisor 3,053 $/yr 15% of operator costs
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Labor 32,850 $/yr 0.5 hr per shift
Calculated using EPA Cost Manual Section 3.2 Chapter
2, site data.2
Materials 32,850 $/yr 100% of maintenance labor
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Natural gas 737,783 $/yr Utah Utility Natural Gas
Electricity 137,353 $/yr Utah Electricity Data
Total DAC 964,245 $/yr
Capital Recovery 177,794 $/yr CR = CRF*TCI BAAQMD BACT Workbook.4
Property Tax 12,487 $/yr 0.01 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Insurance 12,487 $/yr 0.01 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
General and Administrative 24,975 $/yr 0.02 of TCI
Calculated using EPA Cost Manual Section 3.2 Chapter
2.2
Overhead 45,008 $/yr 0.80 of Labor Costs BAAQMD BACT Workbook.4
Total IAC 272,751 $/yr
Total Annualized Cost (TAC) 1,236,997 $/yr TAC = DAC + IAC
Calculated using EPA Cost Manual Section 3.2
Chapter 2.2
Indirect Annual Cost (IAC)
Utilities
Maintenance
Indirect Cost (IC)
Indirect Installation Costs
Direct Capital Cost (DC)
Purchased Equipment Cost (PEC)
Direct Installation Costs (DI)
Labor
Direct Annual Cost (DAC)
8
Table 2
Paint/Spray Booths - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
Annual VOC emissions 3.0 tpy --
RTO VOC destruction efficiency 99% %--EPA Air Pollution Control Technology Fact Sheet.4
Annual VOC removed by RTO 3.0 tpy --
RTO Cost Effectiveness 415,710 $/ton VOC TAC / (VOC & HAP Destroyed) Calculated from TAC and annual VOC removed.
UDAQ Cost Effectiveness Threshold
for VOC 10,000 $/ton VOC --
Utah Air Quality Board Meeting Agenda for
September 12, 2023. Appendix A, Table 1. Cost
threshold for >2 TPY VOC reduction.10
Table 2c. Carbon Adsorption
Parameter Value Units Description Notes
Q 23,000 ft3/min Waste gas flow rate Value given above.
mvoc 0.7 lb/hr VOC inlet rate Value given above.
cvoc 2.2 ppmv Waste gas VOC concentration Value given above.
Pvoc 3.2E-05 psia Partial pressure of VOC Calculated from Waste Gas VOC Concentration.
kvoc 0.71 -- Empirical parameter
Average value based on range of VOCs in EPA Cost
Calculator for Carbon Adsorbers.11
m0.24--Empirical parameterAverage value based on range of VOCs in EPA Cost
Calculator for Carbon Adsorbers.11
we 0.06 lb VOC/lb
Carbon Equilibrium adsorptivity EPA Cost Calculator for Carbon Adsorber = k x P m .11
wc 0.029 lb VOC/lb
Carbon Working capacity EPA Cost Manual Section 3.1 Chapter 1, Equation
1.15.12
CRR 379 lb/hour Estimated Carbon Replacement Rate
Default value per EPA Cost Calculator for Carbon
Adsorbers.11
8,000
lb
carbon/caniste
r
Carbon Canister Capacity
Based on the sizing for a 4,500 cfm waste gas
flowrate from EPA Cost Calculator for Carbon
Adsorbers: Table B.
11
QA 4,380 hr Time for Adsorption
Default value per EPA Cost Calculator for Carbon
Adsorbers.11
Mc 105,097 lb Estimated Total Carbon Requirement
EPA Cost Calculator for Carbon Adsorbers = (mvoc/wc)
x צA.11
14 # Number of Carbon Canisters Required EPA Cost Calculator for Carbon Adsorbers.11
Tc 112,000 lb Total Carbon Required EPA Cost Calculator for Carbon Adsorbers.11
CC 4.2 $/lb Carbon Cost
EPA Cost Manual Section 3.1 Chapter 1 Carbon
Adsorbers.12
n 5.0 yr Carbon Life
BAAQMD BACT Workbook.4 [i × (1 + i)n] / [(1 + i)n -
1]
CRFcarbon 0.24 -- Capital Recovery Factor (carbon)EPA Cost Manual Section 3.1 Chapter 1.12
n15yrEquipment LifeBAAQMD BACT Workbook.4 [i × (1 + i)n] / [(1 + i)n -
1]
CRFadsorber 0.11 -- Capital Recovery Factor (adsorber)EPA Cost Manual Section 3.1 Chapter 1.12
Interest Rate (i) 7.0 % --
Interest rate for 3rd quarter of 2023, according to
IRS.gov.5
Operator Rate 37 $/hr --
Bureau of Labor Statistics. Hourly mean wage for
Aerospace Engineering and Operations Technologists
and Technicians in Aerospace Product and Parts
Manufacturing in the United States.6
Maintenance Rate 60 $/hr -- Conservatively assumed based on market rates.
1.9 $/therm --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
0.020 $/scf
Converted from value above using factors of 99,976
Btu/therm and 1,020 Btu/scf.
Electricity 0.15 $/kWh --
Bureau of Labor Statistics. Average energy prices for
the United States, Mountain - West region.7
2019 CEPCI Annual Average 608 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
2020 CEPCI Annual Average 596 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
2021 CEPCI Annual Average 708 -- --
Chemical Engineering Plant Cost Index Annual Value
2019.8
Adsorber vessels and carbon cost 78,376 $EPA Cost Manual Section 3.1 Chapter 1.12
Auxiliary equipment cost 2,000 $EPA Cost Manual Section 3.1 Chapter 1.12
Total Equipment Cost 80,376 $EC = Absorber + Auxiliary EPA Cost Manual Section 3.1 Chapter 1.12
Instrumentation 8,038 $0.10 of EC EPA Cost Manual Section 3.1 Chapter 1.12
Sales Tax 5,626 $0.07 of EC Avg 7% Sales Tax in Utah.9
Freight 4,019 $0.05 of EC EPA Cost Manual Section 3.1 Chapter 1.12
Purchased Equipment Cost (PEC)
Cost Information
Cost Effectiveness
Natural Gas
Direct Capital Cost (DC)
9
Table 2
Paint/Spray Booths - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
Parameter Value Units Description Notes
Total PEC 98,059 $
Foundation & Supports 7,845 $ 0.08 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Handling & Erection 13,728 $ 0.14 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Electrical 3,922 $ 0.04 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Piping 1,961 $ 0.02 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Insulation 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Painting 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Total DI 29,418 $
Site Preparation (SP) 0 $ as required Assumed none required.
Building (Bldg) 0 $ as required Assumed none required.
Total Direct Cost (DC)127,477 $DC = PEC + DI + SP + Bldg EPA Cost Manual Section 3.1 Chapter 1.12
Engineering 9,806 $ 0.10 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Construction and field expenses 4,903 $ 0.05 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Start-up 1,961 $ 0.02 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Performance test 981 $ 0.01 of PEC EPA Cost Manual Section 3.1 Chapter 1.12
Total IC 17,651 $
Contractor fees 14,513 $ 0.10(DC + IC)EPA Cost Manual Section 3.1 Chapter 1.12
Contingencies 14,513 $ C = CF(DC + IC)EPA Cost Manual Section 3.1 Chapter 1.12
Total Capital Investment (TCI)174,153 $TC = DC + IC + C + Contractor EPA Cost Manual Section 3.1 Chapter 1.12
Operator 20,300 $/yr 0.5 hr/shift, 3 shift/day EPA Cost Manual Section 3.1 Chapter 1.12
Supervisor 3,045 $/yr 15% of operator costs EPA Cost Manual Section 3.1 Chapter 1.12
Labor 32,760 $/yr 0.5 hr/shift, 3 shift/day EPA Cost Manual Section 3.1 Chapter 1.12
Materials 32,760 $/yr 100% of maintenance labor EPA Cost Manual Section 3.1 Chapter 1.12
Carbon 130,788 $/yr CRF[CC*Tc*1.14]EPA Cost Manual Section 3.1 Chapter 1.12
Labor 2,680 $/yr CRF[Labor Rate*Tc/CRR]EPA Cost Manual Section 3.1 Chapter 1.12
Total DAC 222,333 $/yr
Capital Recovery 19,121 $/yr CRF*TCI BAAQMD BACT Workbook.4
Property Tax 1,742 $/yr 0.01 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
Insurance 1,742 $/yr 0.01 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
General and Administrative 3,483 $/yr 0.02 of TCI EPA Cost Manual Section 3.1 Chapter 1.12
Overhead 47,028 $/yr 0.80 of Labor Costs BAAQMD BACT Workbook.4
Total IAC 73,115 $/yr
Total Annualized Cost ($/yr) 295,448 $/yr TAC = DAC + IAC
Annual VOC emissions 3.0 tpy -- Facility estimate.
VOC Control Efficiency 98% -- --EPA Carbon Adsorbers. Chapter 1.13
Annual VOC Removed by Carbon
Adsorber 2.9 tpy --
Calculated by multiplying Annual VOC Emissions and
VOC Control Efficiency.
Carbon Adsorber Cost Effectiveness 100,303 $/ton VOC --
Calculated from Total Annualized Cost divided by
Annual VOC Removed by Carbon Adsorber.
UDAQ Cost Effectiveness Threshold
for VOC 10,000 $/ton VOC --
Utah Air Quality Board Meeting Agenda for
September 12, 2023. Appendix A, Table 1. Cost
threshold for >2 TPY VOC reduction.10
Notes:
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.Utah Department of Air Quality (2023). Utah Air Quality Board Meeting Tentative Agenda, Tuesday, September 12, 2023. Appendix A, Table 1.
https://documents.deq.utah.gov/air-quality/board/2023/DAQ-2023-006610.pdf
Maintenance
Carbon Replacement
Indirect Annual Cost (IAC)
Cost Effectiveness
National Center for Biotechnology Information (2023). PubChem Compound Summary for CID 7237, O-Xylene. Retrieved August 25, 2023 from
https://pubchem.ncbi.nlm.nih.gov/compound/O-Xylene.
EPA (2017). EPA Air Pollution Control Cost Manual Section 3.2, Chapter 2 - Incinerators and Oxidizers. https://www.epa.gov/sites/default/files/2017-
12/documents/oxidizersincinerators_chapter2_7theditionfinal.pdf
EPA (2022). EPA Air Pollution Control Cost Manual Incinerators and Oxidizers Calculation Spreadsheet. https://www.epa.gov/system/files/other-files/2022-
09/US%20EPA_OAQPS_IncineratorsOxidizers_Calc_Sheet_september_2022.xlsm
EPA (2003). Air Pollution Control Technology Fact Sheet. https://www3.epa.gov/ttncatc1/dir1/fregen.pdf
IRS.gov (2023). Interest Rates Remain the Same for the Third Quarter of 2023. https://www.irs.gov/newsroom/interest-rates-remain-the-same-for-the-third-quarter-of-
2023
Bureau of Labor Statistics (2022). Hourly Mean Wage for Aerospace Engineering and Operations Technologists and Technicians in Aerospace Product and Parts
Manufacturing in the United States. https://beta.bls.gov/dataViewer/view/timeseries/OEUN000000033640017302103
Bureau of Labor Statistics (2023). Average Energy Prices for the United States, Regions, Census Divisions, and Selected Metropolitan Areas.
https://www.bls.gov/regions/midwest/data/averageenergyprices_selectedareas_table.htm
Chemical Engineering Online (2021). Chemical Engineering Plant Cost Index. https://www.chemengonline.com/pci-home
Tax Foundation.org (2023). Utah Tax Rates, Collections, and Burdens.
https://taxfoundation.org/location/utah/#:~:text=How%20does%20Utah's%20tax%20code,tax%20rate%20of%207.19%20percent.
Direct Installation Costs (DI)
Indirect Cost (IC)
Indirect Installation Costs
Direct Annual Cost (DAC)
Labor
10
Table 2
Paint/Spray Booths - RACT Analysis
Northrop Grumman Systems Corporation
Clearfield, Utah
11.
12.
13.
Abbreviations:
ACFM - actual cubic feet per minute hr - hours psi - pounds per square inch
BAAQMD - bay area air quality management district kW - kilowatts psia - actual pounds per square inch
BACT - best achieveable control technology kWh - kilowatt hours RACT - reasonably available control technology
Btu - British thermal unit lb - pounds s - seconds
EPA - environmental protection agency lbmol - pound-moles
scf - standard cubic feet
Û)GHJUHHV)DKUHQKHLW m - meters SCFM - standard cubic feet per minute
ft - feet m
3 - cubic meters tpy - tons per year
ft3/cu ft - cubic feet min - minute VOC - volatile organic compound
g - grams ppmv - parts per million by volume yr - years
EPA (2018). Carbon Adsorbers. Chapter 1. https://www.epa.gov/sites/default/files/2018-10/documents/final_carbonadsorberschapter_7thedition.pdf
EPA (2020). EPA Cost Calculator for Carbon Adsorbers. https://www.epa.gov/sites/default/files/2020-11/epa_carbon_adsorber_calc_sheet_7thedition_nov2020.xlsm
EPA (2017). EPA Cost Manual Section 3.1 Chapter 1 - Carbon Adsorbers. https://www.epa.gov/sites/default/files/2018-
10/documents/final_carbonadsorberschapter_7thedition.pdf
11

27
Confidential
APPENDIX B
RBLC DATA

COMPREHENSIVE REPORT
Report Date:06/16/2023
Facility Information
RBLC ID:KS-0038 (final) Date
Determination
Last Updated:03/01/2023
Corporate/Company
Name:
SPIRIT AEROSYSTEMS, INC. Permit Number:C-13362
Facility Name:SPIRIT AEROSYSTEMS, INC. Permit Date:11/10/2016 (actual)
Facility Contact:ALEX TOBIA 3168693931 [e-mail] FRS Number:110000446688
Facility Description:Spirit AeroSystems, Inc. operates an aerospace parts and assemblies manufacturing facility located at
3801 South Oliver Street, Wichita, Kansas.
SIC Code:3721
Permit Type:B: Add new process to existing facility NAICS Code:336411
Permit URL:http://www.kdheks.gov/bar/spirit/spirit.html
EPA Region:7 COUNTRY:USA
Facility County:SEDGWICK COUNTY
Facility State:KS
Facility ZIP Code:67210
Permit Issued By:KANSAS DEPT. OF HEALTH & ENVIRONMENT, BR. OF AIR & RADIATION, KS (Agency Name)
GYANENDRA PRASAI, PE(Agency Contact) 785-296-6427 [e-mail]
Permit Notes:737 Production Line Expansion from 31 to 57 Airplane Fuselage Per Month
Affected Boundaries: Boundary Type:Class 1 Area State:Boundary:Distance:
INTL BORDER US/Canada Border > 250 km

Process/Pollutant Information
PROCESS
NAME:
CAMO4 Paint Area (North Plant 2 Booth)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes: The North Plant 2 Booth or CAMO4 Paint Area has two processes: Operation 1 (exterior coating of fuselage) Operation 2 (interior coating of
fuselage)
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:2.1500 LB/HR 1-HOUR AVERAGING PERIOD, AT ALL TIMES
Emission Limit 2:6.0100 PPM 1-HOUR AVERAGING PERIOD, AT ALL TIMES
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: N
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:MACT
Control Method:(A) Emissions Control Enclosures (ECEs) with a Regenerative Thermal Oxidizer (RTO) for Interior Coating of
Fuselage (Operation 2)
Est. % Efficiency:48.900
Cost Effectiveness:18852 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:Top-Down BACT Analysis for the North Plant 2 Booth (or CAMO4 Paint Area) included the following: 1.
Thermal Oxidizer at $7,468,545.52 per ton VOC Removed 2. Regenerative Thermal Oxidizer (RTO) at
$89,547.05 per ton VOC Removed 3. Zeolite Concentrator with RTO at $95,407.97 per ton VOC Removed 4.
Emissions Control Enclosures (ECEs) with a RTO at $18,851.69 per ton VOC Removed The RTO for the ECEs
is sized for a 25,000 scfm exhaust flow. The BACT for VOC for Operation 1 (exterior coating of fuselage) in the
CAMO4 Paint Area (booth) shall be compliance with the 40 CFR Part 63 Subpart GG.

Process/Pollutant Information
PROCESS
NAME:
Combination Spray Booth/Oven (IPB4 Spoven)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes: One (1) new combination Spray Booth/Oven (IPB4 Spoven), designated EU-3187S-B4. The spray booth will be heated by a natural gas-fired burner
with a heat input rating of 6.0 MMBtu/hr at full load, operating 16 hours a day, 5 days a week, 50 weeks per year (4,000 hours per year), and has an
exhaust flow rate of 40,000 scfm.
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number:VOC
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:1.3400 LB/HR 1-HOUR AVERAGING PERIOD, AT ALL TIMES
Emission Limit 2:2.3400 PPM 1-HOUR AVERAGING PERIOD, AT ALL TIMES
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:MACT
Control Method:(P) The BACT for VOC shall be the compliance with 40 CFR Part 63 Subpart GG.
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:Other control technologies considered in the BACT analysis: 1. Thermal Oxidizer at $43,922,850.16 per ton of
VOC removed 2. Carbon Adsorption System at $260,894.15 per ton of VOC removed 3. RTO with Concentrator
at $240,662.42 per ton of VOC removed 4. RTO at $225,878.53 per ton of VOC removed

Process/Pollutant Information
PROCESS
NAME:
Combination Spray Booth/Oven (IPB4 Spoven)
Process Type: 19.600 (Misc. Boilers, Furnaces, Heaters)
Primary Fuel: natural gas
Throughput: 6.00 MMBtu/hr
Process Notes: One (1) new combination Spray Booth/Oven (IPB4 Spoven), designated EU-3187S-B4. The spray booth will be heated by a natural gas-fired burner
with a heat input rating of 6.0 MMBtu/hr at full load, operating 16 hours a day, 5 days a week, 50 weeks per year (4,000 hours per year), and has an
exhaust flow rate of 40,000 scfm.
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:0.0054 LB/MMBTU AT ALL TIMES
Emission Limit 2:5.5000 LB/MMSCF AT ALL TIMES
Standard Emission:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:MACT
Control Method:(P) The BACT for VOC shall be the use of pipeline quality natural gas and good combustion practices.
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:In a search of the RBLC database for the previous ten years (2006 - 2016), process 19.600 – Miscellaneous
Boilers, Furnaces, Heaters, only three potential BACT control options for VOC emissions were identified: 1)
Gaseous fuels; 2) Good combustion practices; and 3) Combination of two previous options.

Process/Pollutant Information
PROCESS
NAME:
Sludge Dryer
Process Type: 19.600 (Misc. Boilers, Furnaces, Heaters)
Primary Fuel: Natural gas
Throughput: 0.41 MMBtu/hr
Process Notes: Two (2) existing natural gas-fired sludge dryers, each with a heat input rating of 0.408 MMBtu/hr, will operate at full load for 8,760 hours per year.
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:0.0054 LB/MMBTU AT ALL TIMES
Emission Limit 2:5.5000 LB/MMSCF AT ALL TIMES
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:MACT
Control Method:(P) The BACT for VOC shall be the use of pipeline quality natural gas and good combustion practices.
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:In a search of the RBLC database for the previous ten years (2006 - 2016), process 19.600 – Miscellaneous
Boilers, Furnaces, Heaters, only three potential BACT control options for VOC emissions were identified: 1)
Gaseous fuels; 2) Good combustion practices; and 3) Combination of two previous options.

Facility Information
RBLC ID:OK-0172 (final) Date
Determination
Last Updated:07/06/2016
Corporate/Company
Name:
TINKER AFB LOGISTICS CTR Permit
Number:
2009-394-C(M-4)PSD
Facility Name:MIDWEST CITY AIR DEPOT Permit Date:11/19/2015 (actual)
Facility Contact:COL STEPHANIE WILSON 405-734-2102 [e-mail] FRS Number:109-00090
Facility Description:Tinker AFB is a multi-mission/multi-faceted installation that serves the U.S. Air Force, U.S. Navy, and
other Department of Defense (DoD) organizations. The primary Standard Industrial Classification (SIC)
code is 9711, National Security. It is home to the Oklahoma City Air Logistics Center (OC-ALC) and a
number of associated organizations.
SIC Code:9711
Permit Type:C: Modify process at existing facility NAICS Code:928110
Permit URL:
EPA Region:6 COUNTRY:USA
Facility County:OKLAHOMA
Facility State:OK
Facility ZIP Code:73145
Permit Issued By:OKLAHOMA DEPARTMENT OF ENVIRONMENTAL QUALITY (Agency Name)
MR. LEE WARDEN(Agency Contact) [phone] [e-mail]
Permit Notes:The applicant requests an increase in emissions associated with facilities needed to support the KC-46A program. The applicant discovered
discrepancies in the stripper materials initially proposed in Permit No. 2009-394-C (M-2) PSD. As a result the applicant is requesting a re-opening
of the prior permit and relaxation of the existing VOC emission limits from the previous PSD permit.
Affected Boundaries: Boundary Type:Class 1 Area State:Boundary:Distance:
CLASS1 OK Wichita Mountains 100km - 50km
Facility-wide
Emissions:
Pollutant Name:Facility-wide Emissions Increase:
Volatile Organic Compounds (VOC)319.0000 (Tons/Year)

Process/Pollutant Information
PROCESS
NAME:
CHEMICAL DEPAINTING/AIRCRAFT PAINT STRIPPING/AIRCRAFT PARTS PAINT STRIPPING
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel: NA
Throughput: 0
Process Notes: Tinker AFB will perform surface coating and depainting/stripping for the KC-46A aircraft. The chemical strippers used to remove the residual paint
from the surface of the aircraft as well as the new paint applied to the aircraft will be formulations that meet Aerospace Manufacturing and Rework
Facilities (Aerospace) National Emission Standards for Hazardous Air Pollutants (NESHAP) VOC limits. No VOC controls will be installed at the new
paint hangars.
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:333.3800 TONS YEAR
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: Y
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NSPS , NESHAP , MACT
Control Method:(P) 1.Low VOC vapor press. cleaning solvents and strippers(
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:No
Pollutant/Compliance Notes:

Facility Information
RBLC ID:OK-0171 (final) Date
Determination
Last Updated:07/06/2016
Corporate/Company
Name:
TINKER AFB LOGISTICS CTR Permit
Number:
2009-394-C(M-3)PSD
Facility Name:MIDWEST CITY AIR DEPOT Permit Date:11/18/2015 (actual)
Facility Contact:COL STEPHANIE WILSON 405-734-2102 [e-mail] FRS Number:109-00090
Facility Description:Tinker AFB is a multi-mission/multi-faceted installation that serves the U.S. Air Force, U.S. Navy, and
other Department of Defense (DoD) organizations. The primary Standard Industrial Classification (SIC)
code is 9711, National Security. It is home to the Oklahoma City Air Logistics Center (OC-ALC) and a
number of associated organizations.
SIC Code:9711
Permit Type:C: Modify process at existing facility NAICS Code:928110
Permit URL:
EPA Region:6 COUNTRY:USA
Facility County:OKLAHOMA
Facility State:OK
Facility ZIP Code:73145
Permit Issued By:OKLAHOMA DEPARTMENT OF ENVIRONMENTAL QUALITY (Agency Name)
MR. LEE WARDEN(Agency Contact) [phone] [e-mail]
Permit Notes:The applicant discovered discrepancies in the stripper materials initially included in Permit No. 2009-394-TVR. This is a relaxation of VOC
usage/emission limitation of chemical depainting.
Affected Boundaries: Boundary Type:Class 1 Area State:Boundary:Distance:
CLASS1 OK Wichita Mountains 100km - 50km
Facility-wide
Emissions:
Pollutant Name:Facility-wide Emissions Increase:
Volatile Organic Compounds (VOC)400.0000 (Tons/Year)

Process/Pollutant Information
PROCESS NAME: CHEMICAL DEPAINTING/AIRCRAFT PAINT STRIPPING/AIRCRAFT PARTS PAINT STRIPPING
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel: NA
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Unspecified
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:1605.5600 TONS YEAR
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: Y
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NSPS , NESHAP , MACT
Control Method:(P) 1.Low VOC vapor pressure cleaning solvents and strippers (
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:No
Pollutant/Compliance Notes:

Facility Information
RBLC ID:WA-0347 (final) Date
Determination
Last Updated:05/11/2018
Corporate/Company
Name:
THE BOEING COMPANY Permit
Number:
PSD-12-01
Facility Name:BOEING RENTON Permit Date:02/19/2013
(actual)
Facility Contact:MICHAEL VERHAAR [phone] [e-mail] FRS Number:Not Found
Facility Description:The Boeing Renton facility is located in the city of Renton in King County, Washington, and began operation in
1942. It occupies 339 acres, and currently manufactures parts for and assembles the 737 series airplane model.
The facility is located in the south half of Section 18, Township 23N, Range 5, Willamette Meridian. It is
bounded to the north by Lake Washington, to the south by Airport Way, to the east by Logan Avenue, and to the
west by the Renton Airport
SIC Code:3721
Permit Type:D: Both B (Add new process to existing facility) &C (Modify process at existing facility) NAICS Code:336411
Permit URL:http://www.ecy.wa.gov/programs/air/psd/psd_existingpermits.html
EPA Region:10 COUNTRY:USA
Facility County:KING
Facility State:WA
Facility ZIP Code:98124
Permit Issued By:WASHINGTON STATE DEPARTMENT OF ECOLOGY (ECY); AIR QUALITY PROGRAM (Agency Name)
MR. MARC CROOKS(Agency Contact) [phone] [e-mail]
Permit Notes:
Affected Boundaries: Boundary Type:Class 1 Area State:Boundary:Distance:
CLASS1 WA Alpine Lakes < 100 km
CLASS1 WA Glacier Peak < 100 km
CLASS1 WA Goat Rocks 100km - 50km
CLASS1 WA Mount Adams 100km - 50km
CLASS1 WA Mount Rainier NP < 100 km
CLASS1 WA North Cascades NP 100km - 50km
CLASS1 WA Olympic NP < 100 km
INTL BORDER US/Canada Border 100km - 50km
Facility-wide
Emissions:
Pollutant Name:Facility-wide Emissions Increase:
Volatile Organic Compounds (VOC)750.0000 (Tons/Year)

Process/Pollutant Information
PROCESS NAME: Floor Activities
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 504.00 airplanes per year
Process Notes: Floor activities include but are not limited to spar, wing, and aircraft assembly.
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:458.0000 TONS YEAR
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Vertical Wing Booth (PB5)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:65.0000 LB PER WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Vertical Wing Booth (PB6)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:65.0000 LB PER WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Vertical Wing Booth (PB7)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:65.0000 LB PER WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Corrosion Inhibitor Compound Booth (CB1)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:7.7000 LB/WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Corrosion Inhibitor Compound Booth (CB2)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:7.7000 LB PER WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Corrosion Inhibitor Compound Booth (CB3)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:7.7000 LB PER WING 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: New Paint Hangar (P-7/P-8)
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:1350.0000 LB PER PLANE 12-MONTH ROLLING
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:NESHAP
Control Method:(P) Boeing must comply with all applicable VOC emission standards of the National Emission Standards for
Aerospace Manufacturing and Rework Facilities, 40 C.F.R. Part 63, Subpart GG (Aerospace NESHAP), as in
effect on February 19, 2013
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Facility Information
RBLC ID:WA-0348 (draft) Date
Determination
Last Updated:05/22/2018
Corporate/Company
Name:
THE BOEING COMPANY Permit
Number:
PSD-08-01
AMENDMENT 2
Facility Name:BOEING RENTON Permit Date:02/19/2013
(actual)
Facility Contact:MICHAEL VERHAAR [phone] [e-mail] FRS Number:
Facility Description:The Boeing Renton facility is located in the city of Renton in King County, Washington, and began operation
in 1942. It occupies 339 acres, and currently manufactures parts for and assembles the 737 series airplane
model. The facility is located in the south half of Section 18, Township 23N, Range 5, Willamette Meridian. It
is bounded to the north by Lake Washington, to the south by Airport Way, to the east by Logan Avenue, and
to the west by the Renton Airport
SIC Code:3721
Permit Type:C: Modify process at existing facility NAICS Code:336411
Permit URL:http://www.ecy.wa.gov/programs/air/psd/psd_existingpermits.html
EPA Region:10 COUNTRY:USA
Facility County:KING
Facility State:WA
Facility ZIP Code:98124
Permit Issued By:WASHINGTON STATE DEPARTMENT OF ECOLOGY (ECY); AIR QUALITY PROGRAM (Agency Name)
MR. MARC CROOKS(Agency Contact) [phone] [e-mail]
Permit Notes:Boeing Renton increased VOC emissions at Buildings 4-20, 4-21, 4-81, and 4-82. The 118 tpy VOC limit was eliminated and incoorporated into a
facility limit of 750 tpy in PSD-12-01.
Affected Boundaries: Boundary Type:Class 1 Area State:Boundary:Distance:
CLASS1 WA Alpine Lakes < 100 km
CLASS1 WA Glacier Peak < 100 km
CLASS1 WA Goat Rocks 100km - 50km
CLASS1 WA Mount Adams 100km - 50km
CLASS1 WA Mount Rainier NP < 100 km
CLASS1 WA North Cascades NP 100km - 50km
CLASS1 WA Olympic NP < 100 km
INTL BORDER US/Canada Border 100km - 50km

Process/Pollutant Information
PROCESS NAME: P1 Painting Operations
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 6.00 depainted airplanes
Process Notes: No more than 6 airplanes may be depainted in Building 5-50 in any 12 consecutive months
POLLUTANT NAME:
CAS Number:
Test Method:
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: Unknown
Case-by-Case Basis:
Other Applicable Requirements:NESHAP
Control Method:()
Est. % Efficiency:
Cost Effectiveness:$/ton
Incremental Cost Effectiveness:$/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Process/Pollutant Information
PROCESS NAME: Final exterior coating Building 5-50
Process Type: 41.001 (Aerospace Surface Coating)
Primary Fuel:
Throughput: 0
Process Notes:
POLLUTANT NAME: Volatile Organic Compounds (VOC)
CAS Number: VOC
Test Method:Other
Other Test Method:mass ballance
Pollutant Group(s):( Volatile Organic Compounds (VOC) )
Emission Limit 1:40.8000 TONS 12 CONSECUTIVE MONTHS
Emission Limit 2:
Standard Emission:
Did factors, other then air pollution technology considerations influence the BACT decisions: U
Case-by-Case Basis:BACT-PSD
Other Applicable Requirements:
Control Method:(P) low VOC primers, coatings, and solvents. Application requirements. composite vapor pressure of 45 mm Hg
Control Method:(P) low VOC primers, coatings, and solvents. Application requirements. composite vapor pressure of 45 mm Hg
@ 20 degree C
Est. % Efficiency:
Cost Effectiveness:0 $/ton
Incremental Cost Effectiveness:0 $/ton
Compliance Verified:Unknown
Pollutant/Compliance Notes:

Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: MAPLE CREEK ENERGY LLC 
RBLC ID:*IN-0365
+Corporate/Company
Name:
+Facility Name:MAPLE CREEK ENERGY LLC
Facility State:IN
+SIC Code:4911
NAICS Code:221112
Permit Issuance Date:06/19/2023 ACT
Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Combined Cycle Turbine CTGA
+Process Type:15.210
Primary Fuel:Natural Gas
Throughput:3800.00
Throughput Unit:MMBtu per hour

Pollutant Information: MAPLE CREEK ENERGY LLC - Combined Cycle Turbine CTGA 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Oxidation catalyst

+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Selective catalytic reduction system and dry-low-NOx combustors

+Pollutant Name Ammonia (NH3)
+CAS Number:7664-41-7
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Oxidation catalyst

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:

+Pollutant Name Sulfuric Acid (mist, vapors, etc)
+CAS Number:7664-93-9
+Control Method
Description:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Combined Cycle Turbine CTGB
+Process Type:15.210
Primary Fuel:natural gas
Throughput:4200.00
Throughput Unit:MMBtu per hour

Pollutant Information: MAPLE CREEK ENERGY LLC - Combined Cycle Turbine CTGB 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:catalytic oxidation

+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Selective Catalytic Reduction system and dry-low-NOx combustors.

+Pollutant Name Ammonia (NH3)
+CAS Number:7664-41-7
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:oxidation catalyst

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:

+Pollutant Name Sulfuric Acid (mist, vapors, etc)
+CAS Number:7664-93-9
+Control Method
Description:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Auxiliary Boiler
+Process Type:13.310
Primary Fuel:Natural gas
Throughput:96.00
Throughput Unit:MMBtu per hour

Pollutant Information: MAPLE CREEK ENERGY LLC - Auxiliary Boiler 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:

+Pollutant Name Sulfuric Acid (mist, vapors, etc)
+CAS Number:7664-93-9
+Control Method
Description:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Emergency generator
+Process Type:17.110
Primary Fuel:Ultra low sulfur diesel
Throughput:2012.00
Throughput Unit:hp

Pollutant Information: MAPLE CREEK ENERGY LLC - Emergency generator 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Emergency fire pump
+Process Type:17.110
Primary Fuel:Diesel
Throughput:420.00
Throughput Unit:brake hp

Pollutant Information: MAPLE CREEK ENERGY LLC - Emergency fire pump 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:

+Pollutant Name Sulfuric Acid (mist, vapors, etc)
+CAS Number:7664-93-9
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Combined Cycle Turbine CTGA SU/SD
+Process Type:15.210
Primary Fuel:Natural gas
Throughput:3800.00
Throughput Unit:MMBtu per hour

Pollutant Information: MAPLE CREEK ENERGY LLC - Combined Cycle Turbine CTGA SU/SD 
+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:

Process Information: MAPLE CREEK ENERGY LLC 
+Process Name:Combined Cycle Turbine CTGB SU/SD
+Process Type:15.210
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: MAPLE CREEK ENERGY LLC - Combined Cycle Turbine CTGB SU/SD 
+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:

Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: NUCOR STEEL 
RBLC ID:IN-0359
+Corporate/Company
Name:NUCOR STEEL
+Facility Name:NUCOR STEEL
Facility State:IN
+SIC Code:3312
NAICS Code:331111
Permit Issuance Date:03/30/2023 ACT
Process Information: NUCOR STEEL 
+Process Name:Cleaning Section for Galvanizing Line 
+Process Type:81.290
Primary Fuel:NA
Throughput:76.00
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Cleaning Section for Galvanizing Line 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:wet scrubber

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:wet scrubber 

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:wet scrubber

+Pollutant Name Particulate matter, fugitive
+CAS Number:PM
+Control Method
Description:close building doors, hood system design

Process Information: NUCOR STEEL 
+Process Name:Hot Water Circuit Burner for Galvanizing Line 
+Process Type:13.310
Primary Fuel:natural gas 
Throughput:9.00
Throughput Unit:MMBtu/hr

Pollutant Information: NUCOR STEEL - Hot Water Circuit Burner for Galvanizing Line 
+Pollutant Name Particulate matter, filterable (FPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
low NOx burners, good combustion practices, use of pipeline quality
natural gas

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:Only pipeline quality natural gas shall be combusted

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:good combustion practices

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good combustion practices

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

Process Information: NUCOR STEEL 
+Process Name:Annealing Furnace for Galvanizing Line 
+Process Type:81.290
Primary Fuel:natural gas
Throughput:53.10
Throughput Unit:MMBtu/hr

Pollutant Information: NUCOR STEEL - Annealing Furnace for Galvanizing Line 
+Pollutant Name Particulate matter, filterable (FPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:low NOx burners and good combustion practices

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:using good combustion practices and use of natural gas fuel

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted

Process Information: NUCOR STEEL 
+Process Name:Chemical Passivation for Galvanizing Line 
+Process Type:81.290
Primary Fuel:
Throughput:76.00
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Chemical Passivation for Galvanizing Line 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Only waterborne, low solvent or organic coating shall be used.

Process Information: NUCOR STEEL 
+Process Name:Electrostatic Oiler for Galvanizing Line 
+Process Type:81.290
Primary Fuel:
Throughput:76.00
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Electrostatic Oiler for Galvanizing Line 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
+Control Method
Description:use of low VOC oils and good operating practices

Process Information: NUCOR STEEL 
+Process Name:Precleaning and Cleaning Section for Sheet Metal Coating Line
+Process Type:81.290
Primary Fuel:
Throughput:73.80
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Precleaning and Cleaning Section for Sheet Metal Coating
Line 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:wet scrubber

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:wet scrubber

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:wet scrubber

+Pollutant Name Particulate matter, fugitive
+CAS Number:PM
+Control Method
Description:close building doors, hood system design

Process Information: NUCOR STEEL 
+Process Name:Hot Water Circuit Burner for Sheet Metal Coating Line
+Process Type:13.310
Primary Fuel:natural gas
Throughput:5.12
Throughput Unit:MMBtu/hr

Pollutant Information: NUCOR STEEL - Hot Water Circuit Burner for Sheet Metal Coating Line 
+Pollutant Name Particulate matter, filterable (FPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
low NOx burners, good combustion practices and only pipeline quality
natural gas shall be combusted

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:good combustion practices

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good combustion practices

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
good combustion practices and only pipeline quality natural gas shall be
combusted

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

Process Information: NUCOR STEEL 
+Process Name:Chemical Passivation for Sheet Metal Coating Line
+Process Type:81.290
Primary Fuel:
Throughput:73.90
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Chemical Passivation for Sheet Metal Coating Line 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Only waterborne, low solvent or organic coating shall be used.

Process Information: NUCOR STEEL 
+Process Name:Sheet Metal Coating Line with Ovens and RTO
+Process Type:81.290
Primary Fuel:
Throughput:73.90
Throughput Unit:tons per hour

Pollutant Information: NUCOR STEEL - Sheet Metal Coating Line with Ovens and RTO 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:good combustion practices

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:good combustion practices and use of pipeline quality natural gas

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:good combustion practices and use of pipeline quality natural gas

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:low NOx burners and good combustion practices

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:good combustion practices

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:recuperative thermal oxidizer (RTO)

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted. 

Process Information: NUCOR STEEL 
+Process Name:Boiler (CC-BOIL)
+Process Type:13.310
Primary Fuel:natural gas 
Throughput:50.00
Throughput Unit:MMBtu/hr

Pollutant Information: NUCOR STEEL - Boiler (CC-BOIL) 
+Pollutant Name Particulate matter, filterable (FPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:low NOx burners

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:good combustion practices

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good combustion practices and natural gas fuel (clean fuel)

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted.

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
energy efficiency measures and only pipeline quality natural gas fuel shall
be combusted

Process Information: NUCOR STEEL 
+Process Name:Diesel Storage Tank (DST #6)
+Process Type:49.999
Primary Fuel:
Throughput:1000.00
Throughput Unit:gallons storage capacity

Pollutant Information: NUCOR STEEL - Diesel Storage Tank (DST #6) 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:submerged fill pipe and white painted tank shell and roof

Process Information: NUCOR STEEL 
+Process Name:Emergency Generator (CC-GEN1)
+Process Type:17.110
Primary Fuel:diesel
Throughput:3000.00
Throughput Unit:Horsepower

Pollutant Information: NUCOR STEEL - Emergency Generator (CC-GEN1) 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:certified engine

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:ultra-low sulfur diesel fuel (0.0015%S) 

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:oxidation catalyst and certified engine

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:certified engine

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Good engineering design and manufacturer’s recommended operating and
maintenance procedures. 

Process Information: NUCOR STEEL 
+Process Name:Emergency Generator (CC-GEN2)
+Process Type:17.210
Primary Fuel:diesel 
Throughput:500.00
Throughput Unit:Horsepower

Pollutant Information: NUCOR STEEL - Emergency Generator (CC-GEN2) 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:certified engine

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
+Control Method
Description:certified engine

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:ultra-low sulfur diesel fuel (0.0015%S) 

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:oxidation catalyst and certified engine

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:certified engine

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Good engineering design and manufacturer’s recommended operating and
maintenance procedures. 

Process Information: NUCOR STEEL 
+Process Name:Paved Roads
+Process Type:99.140
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: NUCOR STEEL - Paved Roads 
+Pollutant Name Particulate matter, fugitive
+CAS Number:PM
+Control Method
Description:comply with fugitive dust control plan

Process Information: NUCOR STEEL 
+Process Name:laminar cooling tower (contact type)
+Process Type:81.290
Primary Fuel:
Throughput:31600.00
Throughput Unit:gallons/minute

Pollutant Information: NUCOR STEEL - laminar cooling tower (contact type) 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:high efficiency drift eliminators

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:high efficiency drift eliminators

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:high efficiency drift eliminators

Process Information: NUCOR STEEL 
+Process Name:Tunnel Furnace No. 1 
+Process Type:81.220
Primary Fuel:Natural gas 
Throughput:502.00
Throughput Unit:tons/hour

Pollutant Information: NUCOR STEEL - Tunnel Furnace No. 1 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Particulate matter, filterable < 2.5 µ (FPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:low NOx burners (LNB) and good combustion practices

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:good combustion practices

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good combustion practices

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

Process Information: NUCOR STEEL 
+Process Name:Tunnel Furnace No. 2
+Process Type:81.220
Primary Fuel:natural gas 
Throughput:502.00
Throughput Unit:tons/hour

Pollutant Information: NUCOR STEEL - Tunnel Furnace No. 2 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:low NOx burners 

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:Only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good combustion practices

+Pollutant Name Lead (Pb) / Lead Compounds
+CAS Number:7439-92-1
+Control Method
Description:only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Mercury
+CAS Number:7439-97-6
+Control Method
Description:only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Beryllium / Beryllium Compounds
+CAS Number:7440-41-7
+Control Method
Description:only pipeline quality natural gas fuel shall be combusted 

+Pollutant Name Carbon Dioxide
+CAS Number:124-38-9
+Control Method
Description:
good combustion practices and only pipeline quality natural gas fuel shall
be combusted 

Process Information: NUCOR STEEL 
+Process Name:Continuous Casters CC #1 and CC #2
+Process Type:81.350
Primary Fuel:
Throughput:502.00
Throughput Unit:tons/hour (total)

Pollutant Information: NUCOR STEEL - Continuous Casters CC #1 and CC #2 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:
baghouse for upper mold portions and good operating practices for lower
mold portions 

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
baghouse for upper mold portions and good operating practices for lower
mold portions 

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
baghouse for upper mold portions and good operating practices for lower
mold portions 

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:good operating practices

+Pollutant Name Sulfur Dioxide (SO2)
+CAS Number:7446-09-5
+Control Method
Description:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:good operating practices

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:good operating practices

Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
RBLC ID:TX-0955
+Corporate/Company
Name:INEOS OLIGOMERS USA LLC
+Facility Name:INEOS OLIGOMERS CHOCOLATE BAYOU
Facility State:TX
+SIC Code:2869
NAICS Code:325199
Permit Issuance Date:03/14/2023 ACT
Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:COOLING TOWER HEAT EXCHANGER
+Process Type:99.999
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - COOLING TOWER HEAT
EXCHANGER 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Monthly monitoring of Cooling Water return to the tower to watch for
heat exchanger leaks

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:EQUIPMENT FUGITIVES
+Process Type:64.002
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - EQUIPMENT FUGITIVES 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
TCEQ 28LAER leak detection and repair (LDAR) quarterly instrument
monitoring program with weekly AVO walk through checks and
instrument directed repair

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:Fixed roof storage tanks
+Process Type:42.009
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - Fixed roof storage tanks 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Fixed roof tanks, painted white, has submerged fill. Air, nitrogen other
purge gas, fans, blowers, or air movers may not be used on the tank,
unless all the forced ventilated vapors are directed to control. Vacuum
truck vents must limit VOC concentration to 100 ppmv. Frac Tanks with
breathing potential must be white and bottom filled.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:Internal Floating Roof Storage Tanks Normal and MSS
+Process Type:42.009
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - Internal Floating Roof
Storage Tanks Normal and MSS 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Painted white, mechanical shoe primary seal, drain to 9 gal max and 99.9
% destruction efficiency by the thermal oxidizer (THOX) or 98 % control
by flare. Degassing for de-inventory / maintenance must achieve a vapor
concentration 

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:PAO Truck & Rail Loading
+Process Type:64.005
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - PAO Truck & Rail Loading 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Truck and railcar loading of Poly Alpha Olefin products is not required to
be controlled since the vapor pressures of these materials are less than
0.002 psia. No loading through defective lines or components, loading
must stop if liquid leaks are detected. All loading shall be submerged or
bottom loading. Truck and railcar loading of Linear Alpha Olefin products
with vapor pressures over 0.1 psia are captured and directed to thermal
oxidizer control and products with vapor pressures under 0.1 psia
(actually less than 0.01 psia) are not required to be directed to add on
control. Products with a VOC vapor pressure over 0.1 psia (lower than
tier 1 BACT of 0.5psia), are directed to the thermal oxidizer for control.
Tanks trucks handling liquids with a VOC vapor pressure over 0.10 psia
must pass vapor tightness testing every 12 months using the methods
described in Title 40 Code of Federal Regulations Part 63 (40 CFR 63),
Subpart R, assumed to achieve a 99.2% capture. Railcar tankers handling
liquids with a VOC vapor pressure over 0.10 psia must have a current
certification in accordance with U.S. Department of Transportation (DOT)
pressure test requirements of 49 CFR §173.31, assumed to achieve 100%
capture. All loading lines and connectors must be visually inspected for
defects before loading and not used if damaged and loading must be
stopped if a leak is detected. The thermal oxidizer has a 99.9% destruction
efficiency. All loading shall be submerged or bottom loading.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:Process vessel vents and MSS emissions
+Process Type:64.003
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - Process vessel vents and
MSS emissions 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Vessel piping directs normal and MSS waste gas to the thermal oxidizer
for a 99.9 % destruction efficiency or the flare as necessary for a 98 %
destruction efficiency. Capture systems have monthly AVO checks with a
Method 21 leak check and no bypass is authorized. The MSS VOC vapors
to atmosphere must be less than 10,000 ppmv as methane or 3% of the
LEL. Vacuum truck vents must limit VOC concentration to 100 ppmv.
Frac Tanks with breathing potential must be white and bottom filled. Air,
nitrogen other purge gas, fans, blowers, or air movers may not be used on
the equipment or vessel being cleared when it is open to the atmosphere.
The thermal oxidizer and then the flare are the add on control for normal
process waste gas and MSS emissions where vessels and equipment
contain VOC with a partial pressure greater than 0.10 psia. The thermal
oxidizer and flare have a monthly AVO capture check and annual
instrument monitoring and are not authorized for bypass. Vacuum trucks
and frac tanks may be used in MSS liquid removal with control. Vessel
degassing to the atmosphere occurs after de-inventory and dilution of
liquids, depressurization, and vessel purging to control. 

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:THERMAL OXIDIZER
+Process Type:19.200
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - THERMAL OXIDIZER 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Burner design for good combustion and to minimize NOx formation.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:FLARE
+Process Type:19.310
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - FLARE 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Burner tip design and supplemental fuel control assure combustion, open
air combustion does not add temperature to the NOx formation potential

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:LAO and PAO Barge Loading
+Process Type:64.005
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - LAO and PAO Barge
Loading 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Vacuum loading through a closed vent system to the marine vapor
combustor is required for all loading of liquids with a VOC vapor
pressure over 0.10 psia, to assure 100% capture. All loading lines and
connectors must be visually inspected for defects before loading and not
used if damaged and loading must be stopped if a leak is detected. All
loading shall be submerged or bottom loading.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:Marine Vapor Combustor Unit (MCVU)
+Process Type:19.200
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - Marine Vapor Combustor
Unit (MCVU) 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Burner design for good combustion and to minimize NOx formation.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:HOT OIL HEATER
+Process Type:13.310
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - HOT OIL HEATER 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Burner design for good combustion efficiency and to minimize NOx
formation with a SCR system to further reduce NOx.

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Burner design for high efficiency combustion.

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:HEATER NO 2
+Process Type:13.310
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - HEATER NO 2 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Burner design for good combustion efficiency and to minimize NOx
formation.

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Burner design for good combustion efficiency 

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:Engine Emergency Generator
+Process Type:17.110
Primary Fuel:DIESEL
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - Engine Emergency
Generator 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:TIER III ENGINE, OPERATIONS LIMITED TO 100 HRS/YR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:TIER III

Process Information: INEOS OLIGOMERS CHOCOLATE BAYOU 
+Process Name:FILTER OVEN
+Process Type:19.200
Primary Fuel:NATURAL GAS
Throughput:0
Throughput Unit:

Pollutant Information: INEOS OLIGOMERS CHOCOLATE BAYOU - FILTER OVEN 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Efficiency burner and enclosed combustion

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Efficiency burner and enclosed combustion

Previous Page
Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: SIO INTERNATIONAL WISCONSIN 
RBLC ID:*WI-0324
+Corporate/Company
Name:
+Facility Name:SIO INTERNATIONAL WISCONSIN
Facility State:WI
+SIC Code:7373
NAICS Code:541512
Permit Issuance Date:02/28/2023 ACT
Process Information: SIO INTERNATIONAL WISCONSIN 
+Process Name:Small Internal Combustion Engines
+Process Type:17.230
Primary Fuel:Natural Gas
Throughput:0
Throughput Unit:

Pollutant Information: SIO INTERNATIONAL WISCONSIN - Small Internal Combustion Engines 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Use of a 3-way catalyst, engine design, and good combustion practices
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: NORFOLK CRUSH, LLC 
RBLC ID:*NE-0064
+Corporate/Company
+Corporate/Company
Name:NORFOLK CRUSH, LLC
+Facility Name:NORFOLK CRUSH, LLC
Facility State:NE
+SIC Code:2075
NAICS Code:311223
Permit Issuance Date:11/21/2022 ACT
Process Information: NORFOLK CRUSH, LLC 
+Process Name:Boiler A
+Process Type:13.310
Primary Fuel:Natural Gas
Throughput:84.00
Throughput Unit:MMBtu/hr

Pollutant Information: NORFOLK CRUSH, LLC - Boiler A 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Boiler B
+Process Type:13.310
Primary Fuel:Natural Gas
Throughput:84.00
Throughput Unit:MMBtu/hr

Pollutant Information: NORFOLK CRUSH, LLC - Boiler B 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Soybean Oil Extraction 
+Process Type:70.350
Primary Fuel:
Throughput:3960.00
Throughput Unit:ton/day

Pollutant Information: NORFOLK CRUSH, LLC - Soybean Oil Extraction 
+Pollutant Name Hexane
+CAS Number:110-54-3
+Control Method
Description:
Mineral Oil Absorption System (CE-2001). During SSM the source must
comply with 40 CFR 63.2852 as amended March 18, 2020. Leak
detection and repair protocol must be followed.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Grain Receiving
+Process Type:70.230
Primary Fuel:
Throughput:3960.00
Throughput Unit:ton/day

Pollutant Information: NORFOLK CRUSH, LLC - Grain Receiving 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Fabric Filter Baghouse and choke feed practices
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Fabric Filter Baghouse and choke feed practices
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Grain Storage Bins
+Process Type:70.290
Primary Fuel:
Throughput:30000.00
Throughput Unit:bu/hr

Pollutant Information: NORFOLK CRUSH, LLC - Grain Storage Bins 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Each grain storage bin is equipped with a vent filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Each grain storage bin is equipped with a vent filter.
Standard Emission
Limit:0
Standard Emission
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Scalper
+Process Type:70.290
Primary Fuel:
Throughput:15000.00
Throughput Unit:bu/day

Pollutant Information: NORFOLK CRUSH, LLC - Scalper 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:The scalper is equipped with a fabric filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:The scalper is equipped with a fabric filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Main Prep
+Process Type:70.290
Primary Fuel:
Throughput:1980.00
Throughput Unit:ton/day

Pollutant Information: NORFOLK CRUSH, LLC - Main Prep 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
The units will utilized either a cyclone in series with a fabric filter, a
fabric filter by itself, or a fabric filter baghouse.
Standard Emission
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
The units will utilized either a cyclone in series with a fabric filter, a
fabric filter by itself, or a fabric filter baghouse.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Hull/Meal Hammermilling and Pelletizing 
+Process Type:70.290
Primary Fuel:
Throughput:126.50
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Hull/Meal Hammermilling and Pelletizing 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Hull hammermills and Meal Hammermills are controlled by a fabric filter
baghouse. Pelletizing is controlled by a cyclone.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Hull hammermills and Meal Hammermills are controlled by a fabric filter
baghouse. Pelletizing is controlled by a cyclone.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Desolventizer Toaster Dryer Coolers
+Process Type:70.290
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: NORFOLK CRUSH, LLC - Desolventizer Toaster Dryer Coolers 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Each desolventizer toaster dryer cooler has a cyclone.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Each desolventizer toaster dryer cooler has a cyclone.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Hull Storage Bins
+Process Type:70.290
Primary Fuel:
Throughput:500.00
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Hull Storage Bins 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Each bin is equipped with a vent filter. 
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
+Control Method
Description:Each bin is equipped with a vent filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Hull Overhead Storage Bins
+Process Type:70.290
Primary Fuel:
Throughput:500.00
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Hull Overhead Storage Bins 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Each hull overhead storage bin is equipped with a loadout filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Each hull overhead storage bin is equipped with a loadout filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Meal Overhead Storage Bins
+Process Type:70.290
Primary Fuel:
Throughput:500.00
Throughput Unit:tons/hr

Pollutant Information: NORFOLK CRUSH, LLC - Meal Overhead Storage Bins 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Each meal overhead storage bin is equipped with a bin filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Each meal overhead storage bin is equipped with a bin filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Hull Storage Conveyors
+Process Type:70.290
Primary Fuel:
Throughput:500.00
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Hull Storage Conveyors 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:The conveyors are equipped with storage filters.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:The conveyors are equipped with storage filters.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Meal Flat Storage and Conveyors
+Process Type:70.290
Primary Fuel:
Throughput:500.00
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Meal Flat Storage and Conveyors 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:The meal flat storage and its conveyor are controlled by a storage filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:The meal flat storage and its conveyor are controlled by a storage filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Hull and Meal Loadout
+Process Type:70.230
Primary Fuel:
Throughput:1000.00
Throughput Unit:ton/hr

Pollutant Information: NORFOLK CRUSH, LLC - Hull and Meal Loadout 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
The hull and meal loadout operations are inside an enclosed building and
are controlled by a loadout filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
The hull and meal loadout operations are inside an enclosed building and
are controlled by a loadout filter.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Cooling Tower
+Process Type:99.009
Primary Fuel:
Throughput:480060.00
Throughput Unit:gal/hr

Pollutant Information: NORFOLK CRUSH, LLC - Cooling Tower 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:There is a drift loss design specification and a TDS concentration limit.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Emergency Fire Water Pump Engine 1
+Process Type:17.110
Primary Fuel:Diesel
Throughput:510.00
Throughput Unit:hp

Pollutant Information: NORFOLK CRUSH, LLC - Emergency Fire Water Pump Engine 1 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Emergency Fire Water Pump Engine 2
+Process Type:17.210
Primary Fuel:Diesel
Throughput:510.00
Throughput Unit:hp

Pollutant Information: NORFOLK CRUSH, LLC - Emergency Fire Water Pump Engine 2 
+Pollutant Name Particulate matter, total (TPM)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Emergency Generator
+Process Type:17.230
Primary Fuel:Natural Gas
Throughput:620.00
Throughput Unit:hp

Pollutant Information: NORFOLK CRUSH, LLC - Emergency Generator 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Standard Emission
Limit Unit:

Process Information: NORFOLK CRUSH, LLC 
+Process Name:Haul Roads
+Process Type:99.140
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: NORFOLK CRUSH, LLC - Haul Roads 
+Pollutant Name Visible Emissions (VE)
+CAS Number:VE
+Control Method
Description:
Paved roads and Best Management Practices (BMPs) for if sweeping or
water sprays are needed.
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Previous Page
NOTE: Draft determinations are marked with a " * " beside the RBLC ID.
Required fields are denoted by "+".  

Report Date: 09/25/2023            Control Technology Determinations (Freeform) 
Facility Information: SHINTECH PLAQUEMINE PLANT 3 
RBLC ID:LA-0389
+Corporate/Company
Name:SHINTECH LOUISIANA LLC
+Facility Name:SHINTECH PLAQUEMINE PLANT 3
Facility State:LA
+SIC Code:2821
NAICS Code:325211
Permit Issuance Date:10/20/2022 ACT
Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-1 - Scrubber A
+Process Type:63.036
Primary Fuel:
Throughput:930.00
Throughput Unit:MM lbs/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-1 - Scrubber A 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone followed by a wet scrubber
Standard Emission
Limit:0.0017
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone followed by a wet scrubber
Standard Emission
Limit:0.0037
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Steam Strippers and compliance with applicable 40 CFR 63 Subpart
HHHHHHH
Standard Emission
Limit:89.8000
Standard Emission
Limit Unit:PPM

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-2 - Scrubber B
+Process Type:63.036
Primary Fuel:
Throughput:930.00
Throughput Unit:MM lbs/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-2 - Scrubber B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone followed by a wet scrubber
Standard Emission
Limit:0.0017
Standard Emission
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone followed by a wet scrubber
Standard Emission
Limit:0.0037
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Steam stripping and compliance with applicable provisions of 40 CFR 63
Subpart HHHHHHH
Standard Emission
Limit:89.8000
Standard Emission
Limit Unit:PPM

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-3 - Delivery Silo A
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-3 - Delivery Silo A 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-4 - Delivery Silo B
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-4 - Delivery Silo B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-5 - Delivery Silo C
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-5 - Delivery Silo C 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-6 - Delivery Silo D
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-6 - Delivery Silo D 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-7 - Delivery Silo E
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-7 - Delivery Silo E 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-8 - Delivery Silo F
+Process Type:63.036
Primary Fuel:
Throughput:4350.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-8 - Delivery Silo F 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-35 - PVC Plant Thermal Oxidizer A
+Process Type:19.200
Primary Fuel:
Throughput:5.37
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-35 - PVC Plant Thermal
Oxidizer A 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good Combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0231
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Good combustion practices, low NOx burners, and selective catalytic
reduction
Standard Emission
Limit:0.0270
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0
Standard Emission
Limit Unit:LB/DSCF

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:99.9000
Standard Emission
Limit Unit:% DRE

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Energy efficiency measures
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-36 - PVC Plant Thermal Oxidizer B
+Process Type:19.200
Primary Fuel:
Throughput:5.37
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-36 - PVC Plant Thermal
Oxidizer B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good Combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Energy efficiency measures
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0231
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Good combustion practices, low NOx burners, and selective catalytic
reduction
Standard Emission
Limit:0.0270
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0
Standard Emission
Limit Unit:LB/DSCF

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:99.9000
Standard Emission
Limit Unit:% DRE

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-28S - Loading Hoppers Scrubber
+Process Type:63.036
Primary Fuel:
Throughput:2000.00
Throughput Unit:ft^3/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-28S - Loading Hoppers
Scrubber 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Wet Scrubber
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:GR/SCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Wet Scrubber
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:GR/SCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3C-4 - C/A Cooling Tower
+Process Type:63.036
Primary Fuel:
Throughput:64600.00
Throughput Unit:gallons/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3C-4 - C/A Cooling Tower 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-7 - VCM Cooling Tower 1
+Process Type:63.036
Primary Fuel:
Throughput:122269.00
Throughput Unit:gallons/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-7 - VCM Cooling Tower 1 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-18 - VCM Cooling Tower 2
+Process Type:63.036
Primary Fuel:
Throughput:28620.00
Throughput Unit:gallons/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-18 - VCM Cooling Tower 2 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-15 - Cooling Tower
+Process Type:63.036
Primary Fuel:
Throughput:65000.00
Throughput Unit:gallons/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-15 - Cooling Tower 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Drift Eliminator
Standard Emission
Limit:0.0005
Standard Emission
Limit Unit:% DRIFT

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-9 - H/C Cleaning Silo
+Process Type:63.036
Primary Fuel:
Throughput:2000.00
Throughput Unit:SCFM

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-9 - H/C Cleaning Silo 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Cyclone and Fabric Filter
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-CAP - Delivery Silo CAP
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-CAP - Delivery Silo CAP 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-18A - PVC Emergency Combustion Equipment A
+Process Type:17.230
Primary Fuel:
Throughput:100.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-18A - PVC Emergency
Combustion Equipment A 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-18C - PVC Emergency Combustion Equipment C
+Process Type:17.230
Primary Fuel:
Throughput:50.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-18C - PVC Emergency
Combustion Equipment C 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-18E - Emergency Combustion Equipment E
+Process Type:17.230
Primary Fuel:
Throughput:268.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-18E - Emergency Combustion
Equipment E 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate to VOC and NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-18A-F - PVC Emergency Combustion Equipment
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-18A-F - PVC Emergency
Combustion Equipment 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate for VOC and NOx
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Compliance with 40 CFR 60 Subpart IIII using Non-Methane
hydrocarbon + NOx as a surrogate for VOC and NOx
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Energy Efficiency Measures
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:Road - Fugitive Dust (Paved Road)
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - Road - Fugitive Dust (Paved Road) 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Hard Pavement
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Hard Pavement
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3C-6A - C/A Emergency Generators A
+Process Type:63.036
Primary Fuel:Diesel
Throughput:2346.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3C-6A - C/A Emergency
Generators A 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3C-6B - C/A Emergency Generators B
+Process Type:63.036
Primary Fuel:Diesel
Throughput:2346.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3C-6B - C/A Emergency
Generators B 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3C-6C - C/A Emergency Generators C
+Process Type:63.036
Primary Fuel:Diesel
Throughput:2346.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3C-6C - C/A Emergency
Generators C 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx 
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-1 - Cracking Furnace A
+Process Type:63.036
Primary Fuel:
Throughput:90.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-1 - Cracking Furnace A 
+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0460
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction
Standard Emission
Limit:0.0090
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-2 - Cracking Furnace B
+Process Type:63.036
Primary Fuel:
Throughput:90.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-2 - Cracking Furnace B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction
Standard Emission
Limit:0.0090
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0460
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-3 - Cracking Furnace C
+Process Type:63.036
Primary Fuel:
Throughput:90.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-3 - Cracking Furnace C 
+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0460
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction
Standard Emission
Standard Emission
Limit:0.0090
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-4 - Cracking Furnace D
+Process Type:63.036
Primary Fuel:
Throughput:90.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-4 - Cracking Furnace D 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction 
Standard Emission
Limit:0.0090
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0460
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-5 - Gas Thermal Oxidizer A
+Process Type:63.036
Primary Fuel:
Throughput:72.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-5 - Gas Thermal Oxidizer A 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good operating practices
Standard Emission
Limit:99.9900
Standard Emission
Limit Unit:% DRE

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0846
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0195
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0075
Standard Emission
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-6 - Gas Thermal Oxidizer B
+Process Type:63.036
Primary Fuel:
Throughput:72.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-6 - Gas Thermal Oxidizer B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0195
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good operating practices
Standard Emission
Limit:0.0846
Standard Emission
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good operating practices
Standard Emission
Limit:99.9900
Standard Emission
Limit Unit:% DRE

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11A - VCM Emergency Generators A
+Process Type:63.036
Primary Fuel:Diesel
Throughput:2346.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11A - VCM Emergency
Generators A 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11B - VCM Emergency Generators B
+Process Type:63.036
Primary Fuel:Diesel
Throughput:2346.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11B - VCM Emergency
Generators B 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11C - VCM Emergency Pump A
+Process Type:63.036
Primary Fuel:Diesel
Throughput:200.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11C - VCM Emergency Pump
A 
+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11D - VCM Emergency Pump B
+Process Type:63.036
Primary Fuel:Diesel
Throughput:200.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11D - VCM Emergency Pump
B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11E - VCM Emergency Pump C
+Process Type:63.036
Primary Fuel:Diesel
Throughput:200.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11E - VCM Emergency Pump
C 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Comply with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-17 - Cracking Furnace E
+Process Type:63.036
Primary Fuel:
Throughput:90.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-17 - Cracking Furnace E 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas
Standard Emission
Limit:0.0075
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction 
Standard Emission
Limit:0.0090
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0460
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration 
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-1 - Boiler A
+Process Type:63.036
Primary Fuel:
Throughput:250.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-1 - Boiler A 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0362
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction 
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-2 - Boiler B
+Process Type:63.036
Primary Fuel:
Throughput:250.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-2 - Boiler B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction 
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices 
Standard Emission
Limit:0.0362
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices 
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-3 - Boiler C
+Process Type:63.036
Primary Fuel:
Throughput:250.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-3 - Boiler C 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices 
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices 
Standard Emission
Limit:0.0362
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction 
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup 
Standard Emission
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-7A - Fire Water Pump A
+Process Type:63.036
Primary Fuel:Diesel
Throughput:552.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-7A - Fire Water Pump A 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:2.6000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/HP-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-7B - Fire Water Pump B
+Process Type:63.036
Primary Fuel:Diesel
Throughput:552.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-7B - Fire Water Pump B 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Standard Emission
Limit:2.6000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-7C - Fire Water Pump C
+Process Type:63.036
Primary Fuel:Diesel
Throughput:552.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-7C - Fire Water Pump C 
+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:2.6000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.1500
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/HP-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:3.0000
Standard Emission
Limit Unit:G/HP-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-10 - Utility Emergency Generator
+Process Type:63.036
Primary Fuel:Diesel
Throughput:760.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-10 - Utility Emergency
Generator 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-11 - Substation Emergency Generator
+Process Type:63.036
Primary Fuel:Diesel
Throughput:70.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-11 - Substation Emergency
Generator 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:5.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.7000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.7000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-12 - VCM/CA/UT CCR Emergency Generator
+Process Type:63.036
Primary Fuel:Diesel
Throughput:760.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-12 - VCM/CA/UT CCR
Emergency Generator 
+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:6.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-13 - LTY Emergency Generator
+Process Type:63.036
Primary Fuel:Diesel
Throughput:333.30
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-13 - LTY Emergency Generator 
+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.7000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.7000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.4000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:5.0000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:4H-1 - Hydrochloric Acid Production Furnace
+Process Type:63.036
Primary Fuel:
Throughput:51.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 4H-1 - Hydrochloric Acid
Production Furnace 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup
Standard Emission
Limit:0.0030
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Selective catalytic reduction
Standard Emission
Limit:0.0146
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0926
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0141
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-10 - CGF Storage Tank
+Process Type:63.036
Primary Fuel:
Throughput:63072.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-10 - CGF Storage Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-11 - TB Storage Tank
+Process Type:63.036
Primary Fuel:
Throughput:38778.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-11 - TB Storage Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-12 - TE Storage Tank
+Process Type:63.036
Primary Fuel:
Throughput:125462.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-12 - TE Storage Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-13 - TN Storage Tank
+Process Type:63.036
Primary Fuel:
Throughput:51656.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-13 - TN Storage Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-16 - Reactors
+Process Type:63.036
Primary Fuel:
Throughput:1860.00
Throughput Unit:MM lbs/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-16 - Reactors 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Compliance with 40 CFR 63 Subpart HHHHHHH
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-18F - PVC Emergency Combustion Equipment F
+Process Type:63.036
Primary Fuel:Diesel
Throughput:402.00
Throughput Unit:horsepower

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-18F - PVC Emergency
Combustion Equipment F 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0.2000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Compliance with 40 CFR 60 Subpart IIII
Standard Emission
Limit:3.5000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Comply with 40 CFR 60 Subpart IIII using Non-Methane hydrocarbon +
NOx as a surrogate for VOC NOx
Standard Emission
Limit:4.0000
Standard Emission
Limit Unit:G/KW-HR

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-19 - UP Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:75086.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-19 - UP Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-20 - UF Make-up Tank
+Process Type:63.036
Primary Fuel:
Throughput:30034.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-20 - UF Make-up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-21 - UF Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:65074.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-21 - UF Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-22 CG Make-Up Tank
+Process Type:63.036
Primary Fuel:
Throughput:49306.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-22 CG Make-Up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-23 - CG Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:49306.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-23 - CG Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-24 - OZ1 Make Up Tank
+Process Type:63.036
Primary Fuel:
Throughput:37543.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-24 - OZ1 Make Up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-25 - OZ1 Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:37543.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-25 - OZ1 Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-26 - OZ2 Make Up Tank
+Process Type:63.036
Primary Fuel:
Throughput:18771.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-26 - OZ2 Make Up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-27 - OZ2 Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:18771.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-27 - OZ2 Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-28 - IB-ID Loading Hopper
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-28 - IB-ID Loading Hopper 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-29 - IC Loading Hopper
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-29 - IC Loading Hopper 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-30 - IFS Loading Hopper
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-30 - IFS Loading Hopper 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Dust Collector
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:GR/DSCF

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-31 - IFS Make-Up Tank
+Process Type:63.036
Primary Fuel:
Throughput:225257.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-31 - IFS Make-Up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-32 - IFS Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:225257.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-32 - IFS Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-33 - IF Make Up Tank
+Process Type:63.036
Primary Fuel:
Throughput:225257.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-33 - IF Make Up Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-34 - IF Measuring Tank
+Process Type:63.036
Primary Fuel:
Throughput:225257.00
Throughput Unit:gallons/yr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-34 - IF Measuring Tank 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-4 - Boiler D
+Process Type:63.036
Primary Fuel:
Throughput:250.00
Throughput Unit:MM BTU/hr

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-4 - Boiler D 
+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:Good combustion practices and natural gas during startup
Standard Emission
Limit:0.0050
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:Low NOx burners and Selective Catalytic Reduction
Standard Emission
Limit:0.0100
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0362
Standard Emission
Limit Unit:LB/MMBTU

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Good combustion practices
Standard Emission
Limit:0.0026
Standard Emission
Limit Unit:LB/MMBTU

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-8 - VCM Unit Fugitive Emissions
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-8 - VCM Unit Fugitive
Emissions 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Compliance with 40 CFR 63 Subpart H
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-9 - VCM Unit Fugitive Emissions
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-9 - VCM Unit Fugitive
Emissions 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Compliance with 40 CFR 63 Subpart F
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-10 - VCM Unit Fugitive Emissions
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-10 - VCM Unit Fugitive
Emissions 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Compliance with 40 CFR 63 Subpart F
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-6 - Fugitive Emission (Bio)
+Process Type:63.036
Primary Fuel:
Throughput:1350.00
Throughput Unit:gallons/min

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-6 - Fugitive Emission (Bio) 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
+Control Method
Description:Compliance with 40 CFR 63 Subpart H
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:2P-17 - PVC Unit Fugitive Emissions
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 2P-17 - PVC Unit Fugitive
Emissions 
+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:Compliance with 40 CFR 63 Subpart HHHHHHH
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3C-6 - C/A Emergency Generators
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3C-6 - C/A Emergency Generators 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-CAP - Gas Thermal Oxidizer CAP
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-CAP - Gas Thermal Oxidizer
CAP 
+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Energy Efficiency Measures
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3M-11 - VCM Emergency Generators
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3M-11 - VCM Emergency
Generators 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII 
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-CAP - Utility Boiler CAP
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-CAP - Utility Boiler CAP 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:
Improve combustion measures, insulation, and minimization of air
infiltration
Standard Emission
Standard Emission
Limit:0
Standard Emission
Limit Unit:

Process Information: SHINTECH PLAQUEMINE PLANT 3 
+Process Name:3U-7 - Fire Water Pumps
+Process Type:63.036
Primary Fuel:
Throughput:0
Throughput Unit:

Pollutant Information: SHINTECH PLAQUEMINE PLANT 3 - 3U-7 - Fire Water Pumps 
+Pollutant Name Particulate matter, total < 2.5 µ (TPM2.5)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Particulate matter, total < 10 µ (TPM10)
+CAS Number:PM
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Nitrogen Oxides (NOx)
+CAS Number:10102
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Monoxide
+CAS Number:630-08-0
+Control Method
Description:
Standard Emission
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Volatile Organic Compounds (VOC)
+CAS Number:VOC
+Control Method
Description:
Standard Emission
Limit:0
Standard Emission
Limit Unit:

+Pollutant Name Carbon Dioxide Equivalent (CO2e)
+CAS Number:CO2e
+Control Method
Description:Good combustion practices consistent with 40 CFR 60 Subpart IIII
Standard Emission
Limit:0
Standard Emission
Limit Unit:

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