notice of 30-day period for public commentpermits.air.idem.in.gov/41279d.pdfindiana department of...

INDIANA DEPARTMENT OF ENVIRONMENTAL MANAGEMENT We Protect Hoosiers and Our Environment.

100 N. Senate Avenue • Indianapolis, IN 46204

(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov

Eric J. Holcomb Bruno L. Pigott Governor Commissioner

An Equal Opportunity Employer

Recycled Paper

NOTICE OF 30-DAY PERIOD FOR PUBLIC COMMENT

Preliminary Findings Regarding a

Significant Modification to a Part 70 Operating Permit

for Cummins, Inc. Columbus Engine Plant (CEP) in Bartholomew County

Significant Source Modification No.: 005-41279-00015 Significant Permit Modification No.: 005-41384-00015

The Indiana Department of Environmental Management (IDEM) has received an application from Cummins, Inc Columbus Engine Plant (CEB), located at 500 Central Avenue, Columbus, Indiana 47201, for a significant modification of its Part 70 Operating Permit issued on May 29, 2018. If approved by IDEM’s Office of Air Quality (OAQ), this proposed modification would allow Cummins, Inc. Columbus Engine Plant (CEP) LLC to make certain changes at its existing source. Cummins Columbus Engine Plant (CEP) has applied to construct two (2) new test cells, eight (8) new boilers, two (2) new machining operations, and modify one (1) test cell. The applicant intends to construct and operate new equipment that will emit air pollutants; therefore, the permit contains new or different permit conditions. In addition, some conditions from previously issued permits/approvals have been corrected, changed, or removed. These corrections, changes, and removals may include Title I changes (e.g. changes that add or modify synthetic minor emission limits). IDEM has reviewed this application and has developed preliminary findings, consisting of a draft permit and several supporting documents, which would allow the applicant to make this change. A copy of the permit application and IDEM’s preliminary findings are available at:

Bartholomew County Public Library 536 5th Street Columbus, Indiana 47201 and IDEM Southeast Regional Office 820 West Sweet Street Brownstown, IN 47220-9557

A copy of the preliminary findings is available on the Internet at: http://www.in.gov/ai/appfiles/idem-caats/. A copy of the preliminary findings is also available via IDEM’s Virtual File Cabinet (VFC.) Please go to: http://www.in.gov/idem/ and enter VFC in the search box. You will then have the option to search for permit documents using a variety of criteria. How can you participate in this process? The date that this notice is posted on IDEM’s website (https://www.in.gov/idem/5474.htm) marks the beginning of a 30-day public comment period. If the 30th day of the comment period falls on a day when IDEM offices are closed for business, all comments must be postmarked or delivered in person on the next business day that IDEM is open.

http://www.in.gov/ai/appfiles/idem-caats/

http://www.in.gov/idem/

https://www.in.gov/idem/5474.htm

http://www.in.gov/idem/airquality/2356.htm

http://www.in.gov/idem/6900.htm



(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

Mr. David Wehrkamp Cummins Columbus Engine Plant (CEP) 500 Central Avenue Columbus, Indiana 47201

Re: 005-41279-00015 Significant Source Modification

Dear Mr. Wehrkamp:

Cummins, Inc. Columbus Engine Plant (CEP) was issued Part 70 Operating Permit Renewal No. T005-39514-00015 on May 29, 2018 for a stationary internal combustion engine manufacturing, testing, and internal combustion engines source located at 500 Central Avenue, Columbus, Indiana 47201. An application to modify the source was received on March 29, 2019.

Pursuant to the provisions of 326 IAC 2-7-10.5, a Significant Source Modification is hereby

approved as described in the attached Technical Support Document. Pursuant to 326 IAC 2-7-10.5, the following emission units are approved for construction at the

source: (a) Two Electronics Engine Test Cells, consisting of the following:

Emission Unit ID

Date of Construction Maximum Capacity Fuel

Type Control Device

(ID) Stack ID

EU-23 EMC1 Approved in

2019 for construction

605 HP Diesel, Biodiesel, JP-8, or Natural

Gas

none

Stack 23

EU-24 EMC2 1500 HP Stack 24

(b) Eight (8) Natural Gas-fired Boilers, consisting of the following:

Emission Unit Description

Emission Unit ID Date of Construction

Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack

ID

Boiler Cleaver Brooks 1

Approved in 2019 for

construction

0.62 none CB1 Boiler Cleaver Brooks 2 0.62 none CB2 Boiler Cleaver Brooks 3 0.62 none CB3 Boiler Lochinvar 5 0.40 none L5 Boiler Lochinvar 6 0.40 none L6 Boiler Lochinvar 7 0.40 none L7 Boiler Lochinvar 8 0.40 none L8 Boiler Lochinvar 9 0.40 none L9

(c) Two (2) Heavy Duty Machining Operations, identified as HDM-01 and HDM-02, approved in 2019

for construction, with a maximum machining solution usage of 500 gallons per year each, using mist collectors for particulate control, and exhausting indoors.

Cummins (Columbus Engine Plant) Page 2 of 3 Columbus, Indiana SSM No. 005-42179-00015 Permit Reviewer: Iryn Calilung

(d) One (1) Containerized Test Cell, identified as EU-22 LDD6, constructed in 2018, approved in

2019 for modification, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22. The following construction conditions are applicable to the proposed modification:

General Construction Conditions

1. The data and information supplied with the application shall be considered part of this source modification approval. Prior to any proposed change in construction which may affect the potential to emit (PTE) of the proposed project, the change must be approved by the Office of Air Quality (OAQ).

2. This approval to construct does not relieve the Permittee of the responsibility to comply

with the provisions of the Indiana Environmental Management Law (IC 13-11 through 13-20; 13-22 through 13-25; and 13-30), the Air Pollution Control Law (IC 13-17) and the rules promulgated thereunder, as well as other applicable local, state, and federal requirements.

Effective Date of the Permit

3. Pursuant to IC 13-15-5-3, this approval becomes effective upon its issuance.

Commenced Construction 4. Pursuant to 326 IAC 2-1.1-9 and 326 IAC 2-7-10.5(j), the Commissioner may revoke this

approval if construction is not commenced within eighteen (18) months after receipt of this approval or if construction is suspended for a continuous period of one (1) year or more.

5. All requirements and conditions of this construction approval shall remain in effect unless

modified in a manner consistent with procedures established pursuant to 326 IAC 2.

Approval to Construct 6. Pursuant to 326 IAC 2-7-10.5(h)(2), this Significant Source Modification authorizes the

construction of the new emission unit(s), when the Significant Source Modification has been issued.

Pursuant to 326 IAC 2-7-10.5(m), the emission units constructed under this approval shall not be placed into operation prior to revision of the source’s Part 70 Operating Permit to incorporate the required operation conditions. Pursuant to 326 IAC 2-7-12, operation of the new emission unit(s) is not approved until the Significant Permit Modification has been issued. Operating conditions shall be incorporated into the Part 70 Operating Permit as a Significant Permit Modification in accordance with 326 IAC 2-7-10.5(m)(2) and 326 IAC 2-7-12 (Permit Modification).

A copy of the permit is available on the Internet at: http://www.in.gov/ai/appfiles/idem-caats/. A

copy of the permit is also available via IDEM’s Virtual File Cabinet (VFC.) Please go to: http://www.in.gov/idem/ and enter VFC in the search box. You will then have the option to search for permit documents using a variety of criteria. For additional information about air permits and how the public and interested parties can participate, refer to the IDEM Air Permits page on the Internet at: http://www.in.gov/idem/airquality/2356.htm; and the Citizens' Guide to IDEM on the Internet at: http://www.in.gov/idem/6900.htm.


http://www.in.gov/idem/



Cummins (Columbus Engine Plant) Page 3 of 3 Columbus, Indiana SSM No. 005-42179-00015 Permit Reviewer: Iryn Calilung

This decision is subject to the Indiana Administrative Orders and Procedures Act - IC 4-21.5-3-5. If you have any questions regarding this matter, please contact Iryn Calilung, Indiana Department

Environmental Management, Office of Air Quality, Permits Branch, 100 North Senate Avenue, MC 61-53 IGCN 1003, Indianapolis, Indiana 46204-2251, or by telephone at (317) 233-5692 or (800) 451-6027, and ask for Iryn Calilung or (317) 233-5692.

Sincerely,

Iryn Calilung, Section Chief Permits Branch Office of Air Quality

Attachments: Significant Source Modification and Technical Support Document cc: File - Bartholomew County

Bartholomew County Health Department U.S. EPA, Region 5 Compliance and Enforcement Branch IDEM Southeast Regional Office



(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

DRAFT Significant Source Modification

to a Part 70 Source

OFFICE OF AIR QUALITY

Cummins Inc. Columbus Engine Plant (CEP) 1000 5th Street

Columbus, Indiana 47201 (herein known as the Permittee) is hereby authorized to construct subject to the conditions contained herein, the source described in Section A (Source Summary) of this permit. This permit is issued in accordance with 326 IAC 2 and 40 CFR Part 70 Appendix A and contains the conditions and provisions specified in 326 IAC 2-7 as required by 42 U.S.C. 7401, et. seq. (Clean Air Act as amended by the 1990 Clean Air Act Amendments), 40 CFR Part 70.6, IC 13-15 and IC 13-17. This permit also addresses certain new source review requirements for new and/or existing equipment and is intended to fulfill the new source review procedures pursuant to 326 IAC 2-7-10.5, applicable to those conditions. Significant Source Modification No.: 005-41279-00015 Master Agency Interest ID.: 14760 Issued by: Iryn Calilung, Section Chief Permits Branch Office of Air Quality

Issuance Date:

Cummins Inc. Columbus Engine Plant (CEP) Significant Source Modification No. 005-41279-00015 Page 2 of 49 Columbus, Indiana Modified by: Sommer Cochran/Iryn Calilung T005-39514-00015 Permit Reviewer: Sommer Cochran DRAFT

TABLE OF CONTENTS

SECTION A SOURCE SUMMARY ......................................................................................................... 5

A.1 General Information [326 IAC 2-7-4(c)][326 IAC 2-7-5(14)][326 IAC 2-7-1(22)] ................ 5 A.2 Emission Units and Pollution Control Equipment Summary

[326 IAC 2-7-4(c)(3)][326 IAC 2-7-5(14)] ............................................................................ 5 A.3 Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] .................................................. 6 A.4 Non-Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] .................................................. 7 A.5 Part 70 Permit Applicability [326 IAC 2-7-2] ..................................................................... 10

SECTION B GENERAL CONDITIONS ................................................................................................. 11

B.1 Definitions [326 IAC 2-7-1] ................................................................................................ 11 B.2 Permit Term

[326 IAC 2-7-5(2)][326 IAC 2-1.1-9.5][326 IAC 2-7-4(a)(1)(D)][IC 13-15-3-6(a)] ............. 11 B.3 Term of Conditions [326 IAC 2-1.1-9.5] ............................................................................ 11 B.4 Enforceability [326 IAC 2-7-7] [IC 13-17-12] ..................................................................... 11 B.5 Severability [326 IAC 2-7-5(5)] .......................................................................................... 11 B.6 Property Rights or Exclusive Privilege [326 IAC 2-7-5(6)(D)] ........................................... 11 B.7 Duty to Provide Information [326 IAC 2-7-5(6)(E)] ............................................................ 11 B.8 Certification [326 IAC 2-7-4(f)][326 IAC 2-7-6(1)][326 IAC 2-7-5(3)(C)] ........................... 12 B.9 Annual Compliance Certification [326 IAC 2-7-6(5)] ......................................................... 12 B.10 Preventive Maintenance Plan [326 IAC 2-7-5(12)][326 IAC 1-6-3] ................................... 13 B.11 Emergency Provisions [326 IAC 2-7-16] ........................................................................... 14 B.12 Permit Shield [326 IAC 2-7-15][326 IAC 2-7-20][326 IAC 2-7-12] .................................... 15 B.13 Prior Permits Superseded [326 IAC 2-1.1-9.5][326 IAC 2-7-10.5] .................................... 16 B.14 Termination of Right to Operate [326 IAC 2-7-10][326 IAC 2-7-4(a)] ............................... 16 B.15 Permit Modification, Reopening, Revocation and Reissuance, or Termination

[326 IAC 2-7-5(6)(C)][326 IAC 2-7-8(a)][326 IAC 2-7-9] ................................................... 16 B.16 Permit Renewal [326 IAC 2-7-3][326 IAC 2-7-4][326 IAC 2-7-8(e)] .................................. 17 B.17 Permit Amendment or Modification [326 IAC 2-7-11][326 IAC 2-7-12] ............................. 18 B.18 Permit Revision Under Economic Incentives and Other Programs

[326 IAC 2-7-5(8)][326 IAC 2-7-12(b)(2)] .......................................................................... 18 B.19 Operational Flexibility [326 IAC 2-7-20][326 IAC 2-7-10.5]............................................... 18 B.20 Source Modification Requirement [326 IAC 2-7-10.5] ...................................................... 19 B.21 Inspection and Entry [326 IAC 2-7-6][IC 13-14-2-2][IC 13-30-3-1][IC 13-17-3-2] ............. 20 B.22 Transfer of Ownership or Operational Control [326 IAC 2-7-11] ...................................... 20 B.23 Annual Fee Payment [326 IAC 2-7-19] [326 IAC 2-7-5(7)][326 IAC 2-1.1-7] ................... 20 B.24 Advanced Source Modification Approval [326 IAC 2-7-5(15)] [326 IAC 2-7-10.5] ........... 21 B.25 Credible Evidence [326 IAC 2-7-5(3)][326 IAC 2-7-6][62 FR 8314] [326 IAC 1-1-6] ........ 21

SECTION C SOURCE OPERATION CONDITIONS ............................................................................. 22

Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 22 C.1 Particulate Emission Limitations For Processes with Process Weight Rates Less

Than One Hundred (100) Pounds per Hour [326 IAC 6-3-2] ............................................ 22 C.2 Opacity [326 IAC 5-1] ........................................................................................................ 22 C.3 Open Burning [326 IAC 4-1] [IC 13-17-9].......................................................................... 22 C.4 Incineration [326 IAC 4-2] [326 IAC 9-1-2] ........................................................................ 22 C.5 Fugitive Dust Emissions [326 IAC 6-4] ............................................................................. 22 C.6 Asbestos Abatement Projects [326 IAC 14-10] [326 IAC 18] [40 CFR 61, Subpart M] .... 22 Testing Requirements [326 IAC 2-7-6(1)] ................................................................................... 24 C.7 Performance Testing [326 IAC 3-6] .................................................................................. 24 Compliance Requirements [326 IAC 2-1.1-11] .......................................................................... 24 C.8 Compliance Requirements [326 IAC 2-1.1-11] ................................................................. 24


Compliance Monitoring Requirements [326 IAC 2-7-5(1)][326 IAC 2-7-6(1)] .......................... 24 C.9 Compliance Monitoring [326 IAC 2-7-5(3)][326 IAC 2-7-6(1)] .......................................... 24 C.10 Instrument Specifications [326 IAC 2-1.1-11] [326 IAC 2-7-5(3)] [326 IAC 2-7-6(1)] ....... 25 Corrective Actions and Response Steps [326 IAC 2-7-5][326 IAC 2-7-6] ............................... 25 C.11 Emergency Reduction Plans [326 IAC 1-5-2] [326 IAC 1-5-3] ......................................... 25 C.12 Risk Management Plan [326 IAC 2-7-5(11)] [40 CFR 68] ................................................ 25 C.13 Response to Excursions or Exceedances [326 IAC 2-7-5] [326 IAC 2-7-6] ..................... 25 C.14 Actions Related to Noncompliance Demonstrated by a Stack Test

[326 IAC 2-7-5][326 IAC 2-7-6] ......................................................................................... 26 Record Keeping and Reporting Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-19] .............. 26 C.15 Emission Statement

[326 IAC 2-7-5(3)(C)(iii)][326 IAC 2-7-5(7)][326 IAC 2-7-19(c)][326 IAC 2-6] .................. 26 C.16 General Record Keeping Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-6] ................... 27 C.17 General Reporting Requirements [326 IAC 2-7-5(3)(C)] [326 IAC 2-1.1-11].................... 27 Stratospheric Ozone Protection ................................................................................................. 28 C.18 Compliance with 40 CFR 82 and 326 IAC 22-1 ................................................................ 28

SECTION D.1 EMISSIONS UNIT OPERATION CONDITIONS .............................................................. 29

Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 30 D.1.1 Prevention of Significant Deterioration (PSD) Minor Limits [326 IAC 2-2] ........................ 30 D.1.2 BACT Avoidance Limit [326 IAC 8-1-6]............................................................................. 31 D.1.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] ........................................................... 31 Compliance Determination Requirements [326 IAC 2-7-5(1)][326 IAC 2-7-6(1)] .................... 31 D.1.4 Compliance Determination ................................................................................................ 31 Record Keeping and Reporting Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-19] .............. 33 D.1.5 Record Keeping Requirement ........................................................................................... 33 D.1.6 Reporting Requirements ................................................................................................... 33

SECTION D.2 EMISSIONS UNIT OPERATION CONDITIONS .............................................................. 34

Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 35 D.2.1 Particulate Emissions [326 IAC 6-2-4] .............................................................................. 35 D.2.2 Preventive Maintenance Plan [326 IAC 2-7-5(12)] ........................................................... 35

SECTION D.3 EMISSIONS UNIT OPERATION CONDITIONS .............................................................. 36 Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 36 D.3.1 Cold Cleaner Degreaser Control Equipment and Operating Requirements [326 IAC

8-3-2] ................................................................................................................................. 36 D.3.2 Material Requirements for Cold Cleaner Degreasers [326 IAC 8-3-8] ............................. 37 D.3.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] ........................................................... 37 Record Keeping and Reporting Requirement [326 IAC 2-7-19] ............................................... 37 D.3.4 Record Keeping Requirements ......................................................................................... 37

SECTION E.1 NSPS ................................................................................................................................ 38

New Source Performance Standards (NSPS) Requirements [326 IAC 2-7-5(1)] .................... 38 E.1.1 General Provisions Relating to New Source Performance Standards [326 IAC 12-1]

[40 CFR Part 60, Subpart A] ............................................................................................. 38 E.1.2 Standards of Performance for Stationary Compression Ignition Internal Combustion

Engines NSPS [326 IAC 12] [40 CFR Part 60, Subpart IIII] ............................................. 38 Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 39 E.1.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] ........................................................... 39


SECTION E.2 NESHAP ........................................................................................................................... 40

National Emission Standards for Hazardous Air Pollutants (NESHAP) Requirements [326 IAC 2-7-5(1)] ............................................................................................................. 40

E.2.1 General Provisions Relating to National Emission Standards for Hazardous Air Pollutants under 40 CFR Part 63 [326 IAC 20-1] [40 CFR Part 63, Subpart A] ............... 40

E.2.2 Stationary Reciprocating Internal Combustion Engines NESHAP [40 CFR Part 63, Subpart ZZZZ] [326 IAC 20-82] ........................................................................................ 40

Emission Limitations and Standards [326 IAC 2-7-5(1)] .......................................................... 41 E.2.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] ........................................................... 41

CERTIFICATION ........................................................................................................................................ 42

EMERGENCY OCCURRENCE REPORT .................................................................................................. 43

Part 70 Quarterly Report ........................................................................................................................... 45 Part 70 Quarterly Report ........................................................................................................................... 46

Part 70 Quarterly Report ........................................................................................................................... 47

QUARTERLY DEVIATION AND COMPLIANCE MONITORING REPORT .............................................. 48

Attachment A: New Source Performance Standard for Stationary Compression Ignition Internal

Combustion Engines, 40 CFR 60, Subpart IIII Attachment B: National Emission Standards for Hazardous Air Pollutants (NESHAP) for Stationary

Reciprocating Internal Combustion Engines 40 CFR 63, Subpart ZZZZ


SECTION A SOURCE SUMMARY

This permit is based on information requested by the Indiana Department of Environmental Management (IDEM), Office of Air Quality (OAQ). The information describing the source contained in conditions A.1 through A.3 is descriptive information and does not constitute enforceable conditions. However, the Permittee should be aware that a physical change or a change in the method of operation that may render this descriptive information obsolete or inaccurate may trigger requirements for the Permittee to obtain additional permits or seek modification of this permit pursuant to 326 IAC 2, or change other applicable requirements presented in the permit application. A.1 General Information [326 IAC 2-7-4(c)][326 IAC 2-7-5(14)][326 IAC 2-7-1(22)]

The Permittee owns and operates a stationary transportation equipment manufacturing plant.

Source Address: 500 Central Avenue, Columbus, Indiana 47201 General Source Phone Number: 317-412-7919 SIC Code: 3519 County Location: Bartholomew Source Location Status: Attainment for all criteria pollutants Source Status: Part 70 Operating Permit Program Minor Source, under PSD

Minor Source, Section 112 of the Clean Air Act Not 1 of 28 Source Categories

A.2 Emission Units and Pollution Control Equipment Summary

[326 IAC 2-7-4(c)(3)][326 IAC 2-7-5(14)] This stationary source consists of the following emission units and pollution control devices:

(a) One (1) Fuel Test Cell, identified as EU-04 LDTC4, constructed in 2008, with a maximum

capacity of 500 HP, using diesel, biodiesel, or JP-8 fuels, using no controls, and exhausting to Stack 4.

(b) Seven (7) Cycle Test Cells, consisting of the following:

Emission Unit ID

Date of Construction

Maximum Capacity

Fuel Type

Control Device (ID) Stack ID

EU-01 LDTC1

1974 or prior

500 HP

Diesel, Biodiesel, or JP-8

none

Stack 1 EU-02 LDTC2 500 HP Stack 2 EU-03 LDTC3 500 HP Stack 3 EU-05 LDTC5 500 HP Stack 5 EU-06 LDTC6 500 HP Stack 6 EU-07 LDTC7 500 HP Stack 7 EU-08 LDTC8 500 HP Stack 8

(c) Five (5) Production Test Cells, consisting of the following:

Emission Unit

Description Date of

Construction Maximum Capacity Fuel Type

Control Device

(ID) Stack ID

EU-09 LDD1

2008

450 HP Diesel,

Biodiesel, or JP-8

none

Stack 9 EU-10 LDD2 450 HP Stack 10 EU-11 LDD3 450 HP Stack 11 EU-12 LDD4 450 HP Stack 12 EU-17 LDD5 2014 500 HP Stack 17


(d) Four (4) Cold Test Cells, consisting of the following:

Emission Unit ID


Type Control Device

(ID) Stack ID

EU-13

2008

142.86 HP Diesel, Biodiesel, or JP-8

none

Stack 13 EU-14 142.86 HP Stack 14 EU-15 142.86 HP Stack 15 EU-16 142.86 HP Stack 16

(e) Four (4) Hot Test Cells, consisting of the following:

Emission Unit ID


Type Control Device

(ID) Stack ID

EU-18 LDTC9

2014

500 HP Diesel, Biodiesel, or JP-8

none

Stack 18 EU-19 LDTC10 500 HP Stack 19 EU-20 LDTC11 500 HP Stack 20 EU-21 LDTC12 500 HP Stack 21

(f) One (1) Containerized Test Cell, identified as EU-22 LDD6, capable of testing with diesel,

biodiesel, JP-8, natural gas, or gasoline, constructed in 2018 and approved in 2019 for modification, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22.

(g) Two (2) Electronics Engine Test Cells, consisting of the following:

A.3 Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] This stationary source also includes the following insignificant activities which are specifically regulated, as defined in 326 IAC 2-7-1(21):

(a) Three (3) Emergency Generators, consisting of the following:


Emission Unit ID


Maximum Capacity

Control Device

(ID) Stack ID

Diesel-fired Emergency Generator Genset 1 1999 380 HP

none outdoors Diesel-fired Emergency Generator Genset 2 2010 755 HP

Diesel-fired CEP Stationary Fire Pump FP 1 2009 171 HP

[Under 40 CFR 63, Subpart ZZZZ, these are considered affected units.]

[Under 40 CFR 60, Subpart IIII, Genset 2 and FP 1 are considered affected units.]

(b) Sixteen (16) Natural Gas-fired Boilers, consisting of the following:

Emission Unit ID


Maximum Capacity Fuel Type

Control Device

(ID) Stack ID

EU-23 EMC1 Approved in 2019 for

construction

605 HP Diesel, Biodiesel, JP-8, or Natural gas

none Stack 23




Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack

ID

Vertical-fired Tube Steam Boiler B1 2009 2.1 none B1


Hot Water Boiler Raypak-61 Boiler 1 1997 1.5 none indoors



Hot Water Boiler Aerco 96 Boiler 1 1997 0.96 none indoors




Boiler Raypak-72 Boiler 1 2008 1.26 none indoors



Boiler Lochinvar 1 2009 2.075 none B1 Boiler Lochinvar 2 2009 2.075 none B1 Boiler Lochinvar 3 2009 2.075 none B1 Boiler Lochinvar 4 2009 2.075 none B1 Boiler Lochinvar 5 2019* 0.400 none L5 Boiler Lochinvar 6 2019* 0.400 none L6 Boiler Lochinvar 7 2019* 0.400 none L7 Boiler Lochinvar 8 2019* 0.400 none L8 Boiler Lochinvar 9 2019* 0.400 none L9

Boiler Cleaver Brooks 1 2019* 0.620 none CB1



* approved in 2019 for construction (c) Degreasing operations that do not exceed 145 gallons per 12 months, except if subject to

326 IAC 20-6. A.4 Non-Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] This stationary source also includes the following insignificant activities which are not specifically regulated, as defined in 326 IAC 2-7-1(21):

(a) One (1) Battery Assembly Operation, constructed in 2018, with a maximum capacity of

0.3 units per hour, using dry filters for particulate control, and exhausting indoors.


(b) One (1) Welding Operation constructed in 2015, using no controls, exhausting indoors,

and consisting of the following:

Emission Unit Description Emission Unit ID Maximum Capacity TIG Welder T-1 19.5 lbs of wire per hour MIG Welder M-1 11.25 lbs of wire per hour MIG Welder M-2 11.25 lbs of wire per hour

(c) Trimmers that do not produce fugitive emissions and that are equipped with a dust

collection or trim material recovery device such as a bag filter or cyclone. (d) Grinding and machining operations controlled with mist collectors with a design grain

loading of less than or equal to 0.03 grains per actual cubic foot and a gas flow rate less than or equal to 4,000 actual cubic feet per minute, including the following: deburring; buffing; polishing; abrasive blasting; pneumatic conveying; and woodworking operations.

(e) The following VOC and HAP storage containers:

(1) Four (4) Fuel Storage Tanks, constructed in 1991, using no controls, and exhausting to the atmosphere, and consisting of the following:

(i) One (1) Diesel Fuel Storage Tank, identified as Tank 2, having a

maximum capacity of 15,800 gallons (ii) One (1) Engine Oil Storage Tank, identified as Tank 5, having a

maximum storage capacity of 15,800 gallons (iii) One (1) Diesel Fuel Storage Tank, identified as Tank 6, having a

maximum storage capacity of 15,900 gallons (iv) One (1) Certified Test Cell Diesel Fuel Storage Tank, identified as Tank

9, having a maximum storage capacity of 8,200 gallons.

(2) Storage tanks with capacity less than or equal to 1,000 gallons and annual throughputs less than 12,000 gallons.

(3) Vessels storing lubricating oil, hydraulic oils, machining oils, and machining

fluids. (4) Application of oils, greases lubricants or other nonvolatile materials applied as

temporary protective coatings. (f) Machining where an aqueous cutting coolant continuously floods the machining interface. (g) Cleaners and solvents characterized as follows:

(1) having a vapor pressure equal to or less than 2 kiloPascals; 15 millimeters of mercury; or 0.3 pounds per square inch measured at 38°C (100°F) or;

(2) having a vapor pressure equal to or less than 0.7 kiloPascals; 5 millimeters of

mercury; or 0.1 pounds per square inch measured at 20°C (68°F); the use of which for all cleaners and solvents combined does not exceed 145 gallons per 12 months.

(3) Activities associated with the treatment of wastewater streams with an oil and

grease content less than or equal to 1 percent by volume.


(g) Any operation using aqueous solutions containing less than 1 percent by weight of VOCs

excluding HAPs. (h) Noncontact cooling tower system with either forced and/or induced draft cooling tower

system not regulated under a NESHAP. (i) Replacement or repair of filters in air filtration equipment. (j) Asbestos abatement projects regulated by 326 IAC 14-10. (k) Equipment used to collect any material that might be released during a malfunction,

process upset, or spill cleanup, including catch tanks, temporary liquid separators, tanks, and fluid handling equipment.

(l) Blowdown for any of the following: sight glass; boiler; compressors; pumps; and cooling

tower. (m) Paved and unpaved roads and parking lots with public access.

(n) One (1) Paint Booth, identified as PB1, constructed in 2012, with a maximum capacity of

0.3 parts per hour, using dry filters for particulate control, and exhausting to stack PB1.

(o) One hundred and ten (110) Heaters and Air Make Up Units, having a combined maximum heat input capacity of 89.633 MMBtu/hr, using no controls, exhausting outdoors, and consisting of the following:

Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

AHAP 1 1996 3.490 B82 Dock Unit 1 2007 0.320 Roll Up

DR73 5 1996 1.100

AHAP 2 1996 3.490 B82 Dock Unit 2 2007 0.320 Ventilation

Inlet 1 2007 0.823


Inlet 2 2007 0.823


Inlet 3 2007 0.823


Inlet 4 2007 0.823

AHAP 6 1996 2.670 B82 Dock Unit 6 2007 0.320 Viking Chip 1 2007 0.320

AHAP 7 1996 2.000 B82 Dock Unit 7 2007 0.320 Viking Chip 2 2007 0.320

AHAP 8 1996 2.000 CAU-LDTC 1995 0.937 Viking Chip 3 2007 0.320

AHAP 9 1996 2.000 Cell Ventilation 1 2018 0.550 Viking Chip 4 2007 0.320

AHAP 10 1996 3.490 Cell Ventilation 2 2018 0.550 Viking Dock

1 2007 0.320


2 2007 0.320


3 2007 0.320

AHU Hybrid 2010 2.000 Cell Ventilation 5 Viking

Perimeter 1 2007 0.160

AHU-N4A-42 1 2014 2.000 Cell

Ventilation 6 2012 2.700 Viking Perimeter 2 2007 0.160

AHU-N4A-42 2 2014 2.000 Cell

Ventilation 7 Viking Perimeter 3 2007 0.160

B30 1 1996 2.000 Cell Ventilation 8 Viking




B30 3 1996 2.000 Cell Ventilation 10 2014 2.700 Viking




B30 RTU 1996 2.000 Cell Ventilation 12 Viking



Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

B42 Unit 2007 2.000 electric DOC test rig 2013 0.000 Viking


B47 1980 2.000 LDD 1 2007 3.490 Viking Perimeter 10 2007 0.160

B60 Dock Unit 1 2007 2.000 LDD 2 2007 3.490 Viking

Perimeter 11 2007 0.160


Perimeter 12 2007 0.160


Perimeter 13 2007 0.160


Perimeter 14 2007 0.160


Perimeter 15 2007 0.160


Perimeter 16 2007 0.160

B72 Perimeter 1 2007 0.800 LDD 8 2007 2.670 Viking

Perimeter 17 2007 0.160

B72 Perimeter 2 2007 0.557 LDD 9 2007 2.670 Viking

Perimeter 18 2007 0.160

B73 1 2010 0.557 LDD AHU 12 2007 0.030 Viking Perimeter 19 2007 0.160

B73 2 2010 1.000 LDD RTU 10 2008 0.020 Viking Perimeter 20 2007 0.160

B73 3 2010 1.000 LDD RTU 11 1996 0.030 Viking Perimeter 21 2007 0.160

B73 4 2010 1.000 Roll Up DR73 1 1996 1.100 Viking

Perimeter 22 2007 0.160


Perimeter 23 2007 0.160


Perimeter 24 2007 0.160

B73 Conference 1996 0.320 Roll Up DR73

4 1996 1.100 -- -- --

(p) Two (2) Heavy Duty Machining Operations, identified as HDM-01 and HDM-02, approved

in 2019 for construction, with a maximum machining solution usage of 500 gallons per year each, using mist collectors for particulate control, and exhausting indoors.

A.5 Part 70 Permit Applicability [326 IAC 2-7-2]

This stationary source is required to have a Part 70 permit by 326 IAC 2-7-2 (Applicability) because:

(a) It is a major source, as defined in 326 IAC 2-7-1(22);

(b) It is a source in a source category designated by the United States Environmental

Protection Agency (U.S. EPA) under 40 CFR 70.3 (Part 70 - Applicability).


SECTION B GENERAL CONDITIONS

B.1 Definitions [326 IAC 2-7-1] Terms in this permit shall have the definition assigned to such terms in the referenced regulation. In the absence of definitions in the referenced regulation, the applicable definitions found in the statutes or regulations (IC 13-11, 326 IAC 1-2 and 326 IAC 2-7) shall prevail.

B.2 Permit Term [326 IAC 2-7-5(2)][326 IAC 2-1.1-9.5][326 IAC 2-7-4(a)(1)(D)][IC 13-15-3-6(a)]

(a) This permit, T005-39514-00015, is issued for a fixed term of five (5) years from the issuance date of this permit, as determined in accordance with IC 4-21.5-3-5(f) and IC 13-15-5-3. Subsequent revisions, modifications, or amendments of this permit do not affect the expiration date of this permit.

(b) If IDEM, OAQ, upon receiving a timely and complete renewal permit application, fails to

issue or deny the permit renewal prior to the expiration date of this permit, this existing permit shall not expire and all terms and conditions shall continue in effect, including any permit shield provided in 326 IAC 2-7-15, until the renewal permit has been issued or denied.

B.3 Term of Conditions [326 IAC 2-1.1-9.5]

Notwithstanding the permit term of a permit to construct, a permit to operate, or a permit modification, any condition established in a permit issued pursuant to a permitting program approved in the state implementation plan shall remain in effect until:

(a) the condition is modified in a subsequent permit action pursuant to Title I of the Clean Air

Act; or (b) the emission unit to which the condition pertains permanently ceases operation.

B.4 Enforceability [326 IAC 2-7-7] [IC 13-17-12] Unless otherwise stated, all terms and conditions in this permit, including any provisions designed to limit the source's potential to emit, are enforceable by IDEM, the United States Environmental Protection Agency (U.S. EPA) and by citizens in accordance with the Clean Air Act.

B.5 Severability [326 IAC 2-7-5(5)] The provisions of this permit are severable; a determination that any portion of this permit is invalid shall not affect the validity of the remainder of the permit.

B.6 Property Rights or Exclusive Privilege [326 IAC 2-7-5(6)(D)]

This permit does not convey any property rights of any sort or any exclusive privilege. B.7 Duty to Provide Information [326 IAC 2-7-5(6)(E)]

(a) The Permittee shall furnish to IDEM, OAQ, within a reasonable time, any information that IDEM, OAQ may request in writing to determine whether cause exists for modifying, revoking and reissuing, or terminating this permit, or to determine compliance with this permit. Upon request, the Permittee shall also furnish to IDEM, OAQ copies of records required to be kept by this permit.

(b) For information furnished by the Permittee to IDEM, OAQ, the Permittee may include a claim of confidentiality in accordance with 326 IAC 17.1. When furnishing copies of requested records directly to U. S. EPA, the Permittee may assert a claim of confidentiality in accordance with 40 CFR 2, Subpart B.


B.8 Certification [326 IAC 2-7-4(f)][326 IAC 2-7-6(1)][326 IAC 2-7-5(3)(C)]

(a) A certification required by this permit meets the requirements of 326 IAC 2-7-6(1) if: (1) it contains a certification by a "responsible official" as defined by

326 IAC 2-7-1(35), and (2) the certification states that, based on information and belief formed after

reasonable inquiry, the statements and information in the document are true, accurate, and complete.

(b) The Permittee may use the attached Certification Form, or its equivalent with each

submittal requiring certification. One (1) certification may cover multiple forms in one (1) submittal.

(c) A "responsible official" is defined at 326 IAC 2-7-1(35). B.9 Annual Compliance Certification [326 IAC 2-7-6(5)]

(a) The Permittee shall annually submit a compliance certification report which addresses the status of the source’s compliance with the terms and conditions contained in this permit, including emission limitations, standards, or work practices. All certifications shall cover the time period from January 1 to December 31 of the previous year, and shall be submitted no later than July 1 of each year to: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 and United States Environmental Protection Agency, Region 5 Air and Radiation Division, Air Enforcement Branch - Indiana (AE-17J) 77 West Jackson Boulevard Chicago, Illinois 60604-3590

(b) The annual compliance certification report required by this permit shall be considered timely if the date postmarked on the envelope or certified mail receipt, or affixed by the shipper on the private shipping receipt, is on or before the date it is due. If the document is submitted by any other means, it shall be considered timely if received by IDEM, OAQ on or before the date it is due.

(c) The annual compliance certification report shall include the following:

(1) The appropriate identification of each term or condition of this permit that is the basis of the certification;

(2) The compliance status; (3) Whether compliance was continuous or intermittent; (4) The methods used for determining the compliance status of the source, currently

and over the reporting period consistent with 326 IAC 2-7-5(3); and (5) Such other facts, as specified in Sections D of this permit, as IDEM, OAQ may

require to determine the compliance status of the source.


The submittal by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

B.10 Preventive Maintenance Plan [326 IAC 2-7-5(12)][326 IAC 1-6-3]

(a) A Preventive Maintenance Plan (PMP) meets the requirements of 326 IAC 1-6-3 if it includes, at a minimum: (1) Identification of the individual(s) responsible for inspecting, maintaining, and

repairing emission control devices; (2) A description of the items or conditions that will be inspected and the inspection

schedule for said items or conditions; and (3) Identification and quantification of the replacement parts that will be maintained

in inventory for quick replacement. The Permittee shall implement the PMPs.

(b) If required by specific condition(s) in Section D of this permit where no PMP was previously required, the Permittee shall prepare and maintain PMPs no later than ninety (90) days after issuance of this permit or ninety (90) days after initial start-up, whichever is later, including the following information on each facility:

(1) Identification of the individual(s) responsible for inspecting, maintaining, and

repairing emission control devices; (2) A description of the items or conditions that will be inspected and the inspection

schedule for said items or conditions; and (3) Identification and quantification of the replacement parts that will be maintained

in inventory for quick replacement. If, due to circumstances beyond the Permittee’s control, the PMPs cannot be prepared and maintained within the above time frame, the Permittee may extend the date an additional ninety (90) days provided the Permittee notifies: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 The PMP extension notification does not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35). The Permittee shall implement the PMPs.

(c) A copy of the PMPs shall be submitted to IDEM, OAQ upon request and within a reasonable time, and shall be subject to review and approval by IDEM, OAQ. IDEM, OAQ may require the Permittee to revise its PMPs whenever lack of proper maintenance causes or is the primary contributor to an exceedance of any limitation on emissions. The PMPs and their submittal do not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).


(d) To the extent the Permittee is required by 40 CFR Part 60/63 to have an Operation

Maintenance, and Monitoring (OMM) Plan for a unit, such Plan is deemed to satisfy the PMP requirements of 326 IAC 1-6-3 for that unit.

B.11 Emergency Provisions [326 IAC 2-7-16]

(a) An emergency, as defined in 326 IAC 2-7-1(12), is not an affirmative defense for an action brought for noncompliance with a federal or state health-based emission limitation.

(b) An emergency, as defined in 326 IAC 2-7-1(12), constitutes an affirmative defense to an action brought for noncompliance with a technology-based emission limitation if the affirmative defense of an emergency is demonstrated through properly signed, contemporaneous operating logs or other relevant evidence that describe the following: (1) An emergency occurred and the Permittee can, to the extent possible, identify

the causes of the emergency; (2) The permitted facility was at the time being properly operated; (3) During the period of an emergency, the Permittee took all reasonable steps to

minimize levels of emissions that exceeded the emission standards or other requirements in this permit;

(4) For each emergency lasting one (1) hour or more, the Permittee notified IDEM,

OAQ or Southeast Regional Office within four (4) daytime business hours after the beginning of the emergency, or after the emergency was discovered or reasonably should have been discovered; Telephone Number: 1-800-451-6027 (ask for Office of Air Quality, Compliance and Enforcement Branch), or Telephone Number: 317-233-0178 (ask for Office of Air Quality, Compliance and Enforcement Branch) Facsimile Number: 317-233-6865 Southeast Regional Office phone: (812) 358-2027; fax: (812) 358-2058.

(5) For each emergency lasting one (1) hour or more, the Permittee submitted the attached Emergency Occurrence Report Form or its equivalent, either by mail or facsimile to: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 within two (2) working days of the time when emission limitations were exceeded due to the emergency.

The notice fulfills the requirement of 326 IAC 2-7-5(3)(C)(ii) and must contain the following: (A) A description of the emergency;

(B) Any steps taken to mitigate the emissions; and

(C) Corrective actions taken.


The notification which shall be submitted by the Permittee does not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(6) The Permittee immediately took all reasonable steps to correct the emergency.

(c) In any enforcement proceeding, the Permittee seeking to establish the occurrence of an emergency has the burden of proof.

(d) This emergency provision supersedes 326 IAC 1-6 (Malfunctions). This permit condition is in addition to any emergency or upset provision contained in any applicable requirement.

(e) The Permittee seeking to establish the occurrence of an emergency shall make records available upon request to ensure that failure to implement a PMP did not cause or contribute to an exceedance of any limitations on emissions. However, IDEM, OAQ may require that the Preventive Maintenance Plans required under 326 IAC 2-7-4(c)(8) be revised in response to an emergency.

(f) Failure to notify IDEM, OAQ by telephone or facsimile of an emergency lasting more than one (1) hour in accordance with (b)(4) and (5) of this condition shall constitute a violation of 326 IAC 2-7 and any other applicable rules.

(g) If the emergency situation causes a deviation from a technology-based limit, the

Permittee may continue to operate the affected emitting facilities during the emergency provided the Permittee immediately takes all reasonable steps to correct the emergency and minimize emissions.

B.12 Permit Shield [326 IAC 2-7-15][326 IAC 2-7-20][326 IAC 2-7-12]

(a) Pursuant to 326 IAC 2-7-15, the Permittee has been granted a permit shield. The permit shield provides that compliance with the conditions of this permit shall be deemed compliance with any applicable requirements as of the date of permit issuance, provided that either the applicable requirements are included and specifically identified in this permit or the permit contains an explicit determination or concise summary of a determination that other specifically identified requirements are not applicable. The Indiana statutes from IC 13 and rules from 326 IAC, referenced in conditions in this permit, are those applicable at the time the permit was issued. The issuance or possession of this permit shall not alone constitute a defense against an alleged violation of any law, regulation or standard, except for the requirement to obtain a Part 70 permit under 326 IAC 2-7 or for applicable requirements for which a permit shield has been granted. This permit shield does not extend to applicable requirements which are promulgated after the date of issuance of this permit unless this permit has been modified to reflect such new requirements.

(b) If, after issuance of this permit, it is determined that the permit is in nonconformance with an applicable requirement that applied to the source on the date of permit issuance, IDEM, OAQ shall immediately take steps to reopen and revise this permit and issue a compliance order to the Permittee to ensure expeditious compliance with the applicable requirement until the permit is reissued. The permit shield shall continue in effect so long as the Permittee is in compliance with the compliance order.

(c) No permit shield shall apply to any permit term or condition that is determined after issuance of this permit to have been based on erroneous information supplied in the permit application. Erroneous information means information that the Permittee knew to


be false, or in the exercise of reasonable care should have been known to be false, at the time the information was submitted.

(d) Nothing in 326 IAC 2-7-15 or in this permit shall alter or affect the following: (1) The provisions of Section 303 of the Clean Air Act (emergency orders), including

the authority of the U.S. EPA under Section 303 of the Clean Air Act; (2) The liability of the Permittee for any violation of applicable requirements prior to

or at the time of this permit's issuance; (3) The applicable requirements of the acid rain program, consistent with Section

408(a) of the Clean Air Act; and (4) The ability of U.S. EPA to obtain information from the Permittee under Section

114 of the Clean Air Act.

(e) This permit shield is not applicable to any change made under 326 IAC 2-7-20(b)(2) (Sections 502(b)(10) of the Clean Air Act changes) and 326 IAC 2-7-20(c)(2) (trading based on State Implementation Plan (SIP) provisions).

(f) This permit shield is not applicable to modifications eligible for group processing until after IDEM, OAQ, has issued the modifications. [326 IAC 2-7-12(c)(7)]

(g) This permit shield is not applicable to minor Part 70 permit modifications until after IDEM, OAQ, has issued the modification. [326 IAC 2-7-12(b)(8)]

B.13 Prior Permits Superseded [326 IAC 2-1.1-9.5][326 IAC 2-7-10.5]

(a) All terms and conditions of permits established prior to T005-39514-00015 and issued pursuant to permitting programs approved into the state implementation plan have been either: (1) incorporated as originally stated, (2) revised under 326 IAC 2-7-10.5, or (3) deleted under 326 IAC 2-7-10.5.

(b) Provided that all terms and conditions are accurately reflected in this combined permit, all previous registrations and permits are superseded by this combined new source review and part 70 operating permit.

B.14 Termination of Right to Operate [326 IAC 2-7-10][326 IAC 2-7-4(a)]

The Permittee's right to operate this source terminates with the expiration of this permit unless a timely and complete renewal application is submitted at least nine (9) months prior to the date of expiration of the source’s existing permit, consistent with 326 IAC 2-7-3 and 326 IAC 2-7-4(a).

B.15 Permit Modification, Reopening, Revocation and Reissuance, or Termination

[326 IAC 2-7-5(6)(C)][326 IAC 2-7-8(a)][326 IAC 2-7-9] (a) This permit may be modified, reopened, revoked and reissued, or terminated for cause.

The filing of a request by the Permittee for a Part 70 Operating Permit modification, revocation and reissuance, or termination, or of a notification of planned changes or anticipated noncompliance does not stay any condition of this permit. [326 IAC 2-7-5(6)(C)] The notification by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).


(b) This permit shall be reopened and revised under any of the circumstances listed in

IC 13-15-7-2 or if IDEM, OAQ determines any of the following: (1) That this permit contains a material mistake. (2) That inaccurate statements were made in establishing the emissions standards

or other terms or conditions. (3) That this permit must be revised or revoked to assure compliance with an

applicable requirement. [326 IAC 2-7-9(a)(3)]

(c) Proceedings by IDEM, OAQ to reopen and revise this permit shall follow the same procedures as apply to initial permit issuance and shall affect only those parts of this permit for which cause to reopen exists. Such reopening and revision shall be made as expeditiously as practicable. [326 IAC 2-7-9(b)]

(d) The reopening and revision of this permit, under 326 IAC 2-7-9(a), shall not be initiated before notice of such intent is provided to the Permittee by IDEM, OAQ at least thirty (30) days in advance of the date this permit is to be reopened, except that IDEM, OAQ may provide a shorter time period in the case of an emergency. [326 IAC 2-7-9(c)]

B.16 Permit Renewal [326 IAC 2-7-3][326 IAC 2-7-4][326 IAC 2-7-8(e)]

(a) The application for renewal shall be submitted using the application form or forms prescribed by IDEM, OAQ and shall include the information specified in 326 IAC 2-7-4. Such information shall be included in the application for each emission unit at this source, except those emission units included on the trivial or insignificant activities list contained in 326 IAC 2-7-1(21) and 326 IAC 2-7-1(42). The renewal application does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

Request for renewal shall be submitted to:

Indiana Department of Environmental Management Permit Administration and Support Section, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251

(b) A timely renewal application is one that is:

(1) Submitted at least nine (9) months prior to the date of the expiration of this permit; and

(2) If the date postmarked on the envelope or certified mail receipt, or affixed by the

shipper on the private shipping receipt, is on or before the date it is due. If the document is submitted by any other means, it shall be considered timely if received by IDEM, OAQ on or before the date it is due.

(c) If the Permittee submits a timely and complete application for renewal of this permit, the

source’s failure to have a permit is not a violation of 326 IAC 2-7 until IDEM, OAQ takes final action on the renewal application, except that this protection shall cease to apply if, subsequent to the completeness determination, the Permittee fails to submit by the deadline specified, pursuant to 326 IAC 2-7-4(a)(2)(D), in writing by IDEM, OAQ any additional information identified as being needed to process the application.


B.17 Permit Amendment or Modification [326 IAC 2-7-11][326 IAC 2-7-12]

(a) Permit amendments and modifications are governed by the requirements of 326 IAC 2-7-11 or 326 IAC 2-7-12 whenever the Permittee seeks to amend or modify this permit.

(b) Any application requesting an amendment or modification of this permit shall be

submitted to: Indiana Department of Environmental Management Permit Administration and Support Section, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 Any such application does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(c) The Permittee may implement administrative amendment changes addressed in the request for an administrative amendment immediately upon submittal of the request. [326 IAC 2-7-11(c)(3)]

B.18 Permit Revision Under Economic Incentives and Other Programs [326 IAC 2-7-5(8)][326 IAC 2-7-12(b)(2)] (a) No Part 70 permit revision or notice shall be required under any approved economic

incentives, marketable Part 70 permits, emissions trading, and other similar programs or processes for changes that are provided for in a Part 70 permit.

(b) Notwithstanding 326 IAC 2-7-12(b)(1) and 326 IAC 2-7-12(c)(1), minor Part 70 permit modification procedures may be used for Part 70 modifications involving the use of economic incentives, marketable Part 70 permits, emissions trading, and other similar approaches to the extent that such minor Part 70 permit modification procedures are explicitly provided for in the applicable State Implementation Plan (SIP) or in applicable requirements promulgated or approved by the U.S. EPA.

B.19 Operational Flexibility [326 IAC 2-7-20][326 IAC 2-7-10.5]

(a) The Permittee may make any change or changes at the source that are described in 326 IAC 2-7-20(b) or (c) without a prior permit revision, if each of the following conditions is met: (1) The changes are not modifications under any provision of Title I of the Clean Air

Act; (2) Any preconstruction approval required by 326 IAC 2-7-10.5 has been obtained; (3) The changes do not result in emissions which exceed the limitations provided in

this permit (whether expressed herein as a rate of emissions or in terms of total emissions);

(4) The Permittee notifies the:

Indiana Department of Environmental Management Permit Administration and Support Section, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251


and United States Environmental Protection Agency, Region 5 Air and Radiation Division, Regulation Development Branch - Indiana (AR-18J) 77 West Jackson Boulevard Chicago, Illinois 60604-3590

in advance of the change by written notification at least ten (10) days in advance of the proposed change. The Permittee shall attach every such notice to the Permittee's copy of this permit; and

(5) The Permittee maintains records on-site, on a rolling five (5) year basis, which

document all such changes and emission trades that are subject to 326 IAC 2-7-20(b)(1) and (c)(1). The Permittee shall make such records available, upon reasonable request, for public review.

Such records shall consist of all information required to be submitted to IDEM, OAQ in the notices specified in 326 IAC 2-7-20(b)(1) and (c)(1).

(b) The Permittee may make Section 502(b)(10) of the Clean Air Act changes (this term is

defined at 326 IAC 2-7-1(37)) without a permit revision, subject to the constraint of 326 IAC 2-7-20(a). For each such Section 502(b)(10) of the Clean Air Act change, the required written notification shall include the following: (1) A brief description of the change within the source; (2) The date on which the change will occur; (3) Any change in emissions; and (4) Any permit term or condition that is no longer applicable as a result of the

change. The notification which shall be submitted is not considered an application form, report or compliance certification. Therefore, the notification by the Permittee does not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(c) Emission Trades [326 IAC 2-7-20(c)] The Permittee may trade emissions increases and decreases at the source, where the applicable SIP provides for such emission trades without requiring a permit revision, subject to the constraints of Section (a) of this condition and those in 326 IAC 2-7-20(c).

(d) Alternative Operating Scenarios [326 IAC 2-7-20(d)] The Permittee may make changes at the source within the range of alternative operating scenarios that are described in the terms and conditions of this permit in accordance with 326 IAC 2-7-5(9). No prior notification of IDEM, OAQ or U.S. EPA is required.

(e) Backup fuel switches specifically addressed in, and limited under, Section D of this permit shall not be considered alternative operating scenarios. Therefore, the notification requirements of part (a) of this condition do not apply.

B.20 Source Modification Requirement [326 IAC 2-7-10.5]

A modification, construction, or reconstruction is governed by the requirements of 326 IAC 2.


B.21 Inspection and Entry [326 IAC 2-7-6][IC 13-14-2-2][IC 13-30-3-1][IC 13-17-3-2]

Upon presentation of proper identification cards, credentials, and other documents as may be required by law, and subject to the Permittee’s right under all applicable laws and regulations to assert that the information collected by the agency is confidential and entitled to be treated as such, the Permittee shall allow IDEM, OAQ, U.S. EPA, or an authorized representative to perform the following:

(a) Enter upon the Permittee's premises where a Part 70 source is located, or emissions

related activity is conducted, or where records must be kept under the conditions of this permit;

(b) As authorized by the Clean Air Act, IC 13-14-2-2, IC 13-17-3-2, and IC 13-30-3-1, have access to and copy any records that must be kept under the conditions of this permit;

(c) As authorized by the Clean Air Act, IC 13-14-2-2, IC 13-17-3-2, and IC 13-30-3-1, inspect any facilities, equipment (including monitoring and air pollution control equipment), practices, or operations regulated or required under this permit;

(d) As authorized by the Clean Air Act, IC 13-14-2-2, IC 13-17-3-2, and IC 13-30-3-1, sample or monitor substances or parameters for the purpose of assuring compliance with this permit or applicable requirements; and

(e) As authorized by the Clean Air Act, IC 13-14-2-2, IC 13-17-3-2, and IC 13-30-3-1, utilize any photographic, recording, testing, monitoring, or other equipment for the purpose of assuring compliance with this permit or applicable requirements.

B.22 Transfer of Ownership or Operational Control [326 IAC 2-7-11]

(a) The Permittee must comply with the requirements of 326 IAC 2-7-11 whenever the Permittee seeks to change the ownership or operational control of the source and no other change in the permit is necessary.

(b) Any application requesting a change in the ownership or operational control of the source shall contain a written agreement containing a specific date for transfer of permit responsibility, coverage and liability between the current and new Permittee. The application shall be submitted to: Indiana Department of Environmental Management Permit Administration and Support Section, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 Any such application does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(c) The Permittee may implement administrative amendment changes addressed in the request for an administrative amendment immediately upon submittal of the request. [326 IAC 2-7-11(c)(3)]

B.23 Annual Fee Payment [326 IAC 2-7-19] [326 IAC 2-7-5(7)][326 IAC 2-1.1-7]

(a) The Permittee shall pay annual fees to IDEM, OAQ within thirty (30) calendar days of receipt of a billing. Pursuant to 326 IAC 2-7-19(b), if the Permittee does not receive a bill from IDEM, OAQ the applicable fee is due April 1 of each year.

(b) Except as provided in 326 IAC 2-7-19(e), failure to pay may result in administrative

enforcement action or revocation of this permit.


(c) The Permittee may call the following telephone numbers: 1-800-451-6027 or

317-233-4230 (ask for OAQ, Billing, Licensing, and Training Section), to determine the appropriate permit fee.

B.24 Advanced Source Modification Approval [326 IAC 2-7-5(15)] [326 IAC 2-7-10.5]

(a) The requirements to obtain a source modification approval under 326 IAC 2-7-10.5 or a permit modification under 326 IAC 2-7-12 are satisfied by this permit for the proposed emission units, control equipment or insignificant activities in Sections A.2 and A.3.

(b) Pursuant to 326 IAC 2-1.1-9 any permit authorizing construction may be revoked if construction of the emission unit has not commenced within eighteen (18) months from the date of issuance of the permit, or if during the construction, work is suspended for a continuous period of one (1) year or more.

B.25 Credible Evidence [326 IAC 2-7-5(3)][326 IAC 2-7-6][62 FR 8314] [326 IAC 1-1-6]

For the purpose of submitting compliance certifications or establishing whether or not the Permittee has violated or is in violation of any condition of this permit, nothing in this permit shall preclude the use, including the exclusive use, of any credible evidence or information relevant to whether the Permittee would have been in compliance with the condition of this permit if the appropriate performance or compliance test or procedure had been performed.


SECTION C SOURCE OPERATION CONDITIONS

Entire Source Emission Limitations and Standards [326 IAC 2-7-5(1)] C.1 Particulate Emission Limitations For Processes with Process Weight Rates Less Than One

Hundred (100) Pounds per Hour [326 IAC 6-3-2] Pursuant to 326 IAC 6-3-2(e)(2), particulate emissions from any process not exempt under 326 IAC 6-3-1(b) or (c) which has a maximum process weight rate less than 100 pounds per hour and the methods in 326 IAC 6-3-2(b) through (d) do not apply shall not exceed 0.551 pounds per hour.

C.2 Opacity [326 IAC 5-1] Pursuant to 326 IAC 5-1-2 (Opacity Limitations), except as provided in 326 IAC 5-1-1 (Applicability) and 326 IAC 5-1-3 (Temporary Alternative Opacity Limitations), opacity shall meet the following, unless otherwise stated in this permit:

(a) Opacity shall not exceed an average of forty percent (40%) in any one (1) six (6) minute

averaging period as determined in 326 IAC 5-1-4.

(b) Opacity shall not exceed sixty percent (60%) for more than a cumulative total of fifteen (15) minutes (sixty (60) readings as measured according to 40 CFR 60, Appendix A, Method 9 or fifteen (15) one (1) minute nonoverlapping integrated averages for a continuous opacity monitor) in a six (6) hour period.

C.3 Open Burning [326 IAC 4-1] [IC 13-17-9] The Permittee shall not open burn any material except as provided in 326 IAC 4-1-3, 326 IAC 4-1-4 or 326 IAC 4-1-6. The previous sentence notwithstanding, the Permittee may open burn in accordance with an open burning approval issued by the Commissioner under 326 IAC 4-1-4.1.

C.4 Incineration [326 IAC 4-2] [326 IAC 9-1-2]

The Permittee shall not operate an incinerator except as provided in 326 IAC 4-2 or in this permit. The Permittee shall not operate a refuse incinerator or refuse burning equipment except as provided in 326 IAC 9-1-2 or in this permit.

C.5 Fugitive Dust Emissions [326 IAC 6-4]

The Permittee shall not allow fugitive dust to escape beyond the property line or boundaries of the property, right-of-way, or easement on which the source is located, in a manner that would violate 326 IAC 6-4 (Fugitive Dust Emissions). 326 IAC 6-4-2(4) is not federally enforceable.

C.6 Asbestos Abatement Projects [326 IAC 14-10] [326 IAC 18] [40 CFR 61, Subpart M] (a) Notification requirements apply to each owner or operator. If the combined amount of

regulated asbestos containing material (RACM) to be stripped, removed or disturbed is at least 260 linear feet on pipes or 160 square feet on other facility components, or at least thirty-five (35) cubic feet on all facility components, then the notification requirements of 326 IAC 14-10-3 are mandatory. All demolition projects require notification whether or not asbestos is present.

(b) The Permittee shall ensure that a written notification is sent on a form provided by the Commissioner at least ten (10) working days before asbestos stripping or removal work or before demolition begins, per 326 IAC 14-10-3, and shall update such notice as necessary, including, but not limited to the following:


(1) When the amount of affected asbestos containing material increases or

decreases by at least twenty percent (20%); or (2) If there is a change in the following:

(A) Asbestos removal or demolition start date;

(B) Removal or demolition contractor; or

(C) Waste disposal site.

(c) The Permittee shall ensure that the notice is postmarked or delivered according to the guidelines set forth in 326 IAC 14-10-3(2).

(d) The notice to be submitted shall include the information enumerated in 326 IAC 14-10-3(3). All required notifications shall be submitted to: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 The notice shall include a signed certification from the owner or operator that the information provided in this notification is correct and that only Indiana licensed workers and project supervisors will be used to implement the asbestos removal project. The notifications do not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(e) Procedures for Asbestos Emission Control The Permittee shall comply with the applicable emission control procedures in 326 IAC 14-10-4 and 40 CFR 61.145(c). Per 326 IAC 14-10-1, emission control requirements are applicable for any removal or disturbance of RACM greater than three (3) linear feet on pipes or three (3) square feet on any other facility components or a total of at least 0.75 cubic feet on all facility components.

(f) Demolition and Renovation The Permittee shall thoroughly inspect the affected facility or part of the facility where the demolition or renovation will occur for the presence of asbestos pursuant to 40 CFR 61.145(a).

(g) Indiana Licensed Asbestos Inspector The Permittee shall comply with 326 IAC 14-10-1(a) that requires the owner or operator, prior to a renovation/demolition, to use an Indiana Licensed Asbestos Inspector to thoroughly inspect the affected portion of the facility for the presence of asbestos. The requirement to use an Indiana Licensed Asbestos inspector is not federally enforceable.


Testing Requirements [326 IAC 2-7-6(1)] C.7 Performance Testing [326 IAC 3-6]

(a) For performance testing required by this permit, a test protocol, except as provided elsewhere in this permit, shall be submitted to: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 no later than thirty-five (35) days prior to the intended test date. The protocol submitted by the Permittee does not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(b) The Permittee shall notify IDEM, OAQ of the actual test date at least fourteen (14) days prior to the actual test date. The notification submitted by the Permittee does not require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

(c) Pursuant to 326 IAC 3-6-4(b), all test reports must be received by IDEM, OAQ not later than forty-five (45) days after the completion of the testing. An extension may be granted by IDEM, OAQ if the Permittee submits to IDEM, OAQ a reasonable written explanation not later than five (5) days prior to the end of the initial forty-five (45) day period.

Compliance Requirements [326 IAC 2-1.1-11] C.8 Compliance Requirements [326 IAC 2-1.1-11]

The commissioner may require stack testing, monitoring, or reporting at any time to assure compliance with all applicable requirements by issuing an order under 326 IAC 2-1.1-11. Any monitoring or testing shall be performed in accordance with 326 IAC 3 or other methods approved by the commissioner or the U. S. EPA.

Compliance Monitoring Requirements [326 IAC 2-7-5(1)][326 IAC 2-7-6(1)] C.9 Compliance Monitoring [326 IAC 2-7-5(3)][326 IAC 2-7-6(1)]

(a) For new units: Unless otherwise specified in the approval for the new emission unit(s), compliance monitoring for new emission units shall be implemented on and after the date of initial start-up.

(b) For existing units: Unless otherwise specified in this permit, for all monitoring requirements not already legally required, the Permittee shall be allowed up to ninety (90) days from the date of permit issuance to begin such monitoring. If, due to circumstances beyond the Permittee's control, any monitoring equipment required by this permit cannot be installed and operated no later than ninety (90) days after permit issuance, the Permittee may extend the compliance schedule related to the equipment for an additional ninety (90) days provided the Permittee notifies: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251


in writing, prior to the end of the initial ninety (90) day compliance schedule, with full justification of the reasons for the inability to meet this date. The notification which shall be submitted by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

C.10 Instrument Specifications [326 IAC 2-1.1-11] [326 IAC 2-7-5(3)] [326 IAC 2-7-6(1)]

(a) When required by any condition of this permit, an analog instrument used to measure a parameter related to the operation of an air pollution control device shall have a scale such that the expected maximum reading for the normal range shall be no less than twenty percent (20%) of full scale. The analog instrument shall be capable of measuring values outside of the normal range.

(b) The Permittee may request that the IDEM, OAQ approve the use of an instrument that

does not meet the above specifications provided the Permittee can demonstrate that an alternative instrument specification will adequately ensure compliance with permit conditions requiring the measurement of the parameters.

Corrective Actions and Response Steps [326 IAC 2-7-5][326 IAC 2-7-6] C.11 Emergency Reduction Plans [326 IAC 1-5-2] [326 IAC 1-5-3]

Pursuant to 326 IAC 1-5-2 (Emergency Reduction Plans; Submission):

(a) The Permittee shall maintain the most recently submitted written emergency reduction plans (ERPs) consistent with safe operating procedures.

(b) Upon direct notification by IDEM, OAQ that a specific air pollution episode level is in effect, the Permittee shall immediately put into effect the actions stipulated in the approved ERP for the appropriate episode level. [326 IAC 1-5-3]

C.12 Risk Management Plan [326 IAC 2-7-5(11)] [40 CFR 68]

If a regulated substance, as defined in 40 CFR 68, is present at a source in more than a threshold quantity, the Permittee must comply with the applicable requirements of 40 CFR 68.

C.13 Response to Excursions or Exceedances [326 IAC 2-7-5] [326 IAC 2-7-6]

Upon detecting an excursion where a response step is required by the D Section or an exceedance of a limitation in this permit: (a) The Permittee shall take reasonable response steps to restore operation of the emissions

unit (including any control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing excess emissions.

(b) The response shall include minimizing the period of any startup, shutdown or

malfunction. The response may include, but is not limited to, the following: (1) initial inspection and evaluation; (2) recording that operations returned or are returning to normal without operator

action (such as through response by a computerized distribution control system); or

(3) any necessary follow-up actions to return operation to normal or usual manner of

operation.


(c) A determination of whether the Permittee has used acceptable procedures in response to

an excursion or exceedance will be based on information available, which may include, but is not limited to, the following: (1) monitoring results; (2) review of operation and maintenance procedures and records; and/or (3) inspection of the control device, associated capture system, and the process.

(d) Failure to take reasonable response steps shall be considered a deviation from the

permit. (e) The Permittee shall record the reasonable response steps taken.

C.14 Actions Related to Noncompliance Demonstrated by a Stack Test [326 IAC 2-7-5][326 IAC 2-7-6]

(a) When the results of a stack test performed in conformance with Section C - Performance Testing, of this permit exceed the level specified in any condition of this permit, the Permittee shall submit a description of its response actions to IDEM, OAQ no later than seventy-five (75) days after the date of the test.

(b) A retest to demonstrate compliance shall be performed no later than one hundred eighty (180) days after the date of the test. Should the Permittee demonstrate to IDEM, OAQ that retesting in one hundred eighty (180) days is not practicable, IDEM, OAQ may extend the retesting deadline.

(c) IDEM, OAQ reserves the authority to take any actions allowed under law in response to noncompliant stack tests.

The response action documents submitted pursuant to this condition do require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).

Record Keeping and Reporting Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-19] C.15 Emission Statement [326 IAC 2-7-5(3)(C)(iii)][326 IAC 2-7-5(7)][326 IAC 2-7-19(c)][326 IAC 2-6]

Pursuant to 326 IAC 2-6-3(b)(3), starting in 2006 and every three (3) years thereafter, the Permittee shall submit by July 1 an emission statement covering the previous calendar year. The emission statement shall contain, at a minimum, the information specified in 326 IAC 2-6-4(c) and shall meet the following requirements: (1) Indicate estimated actual emissions of all pollutants listed in 326 IAC 2-6-4(a); (2) Indicate estimated actual emissions of regulated pollutants as defined by

326 IAC 2-7-1(33) (“Regulated pollutant, which is used only for purposes of Section 19 of this rule”) from the source, for purpose of fee assessment.

The statement must be submitted to: Indiana Department of Environmental Management Technical Support and Modeling Section, Office of Air Quality 100 North Senate Avenue MC 61-50 IGCN 1003 Indianapolis, Indiana 46204-2251 The emission statement does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35).


C.16 General Record Keeping Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-6]

(a) Records of all required monitoring data, reports and support information required by this permit shall be retained for a period of at least five (5) years from the date of monitoring sample, measurement, report, or application. Support information includes the following, where applicable:

(AA) All calibration and maintenance records. (BB) All original strip chart recordings for continuous monitoring

instrumentation. (CC) Copies of all reports required by the Part 70 permit.

Records of required monitoring information include the following, where applicable:

(AA) The date, place, as defined in this permit, and time of sampling or measurements.

(BB) The dates analyses were performed. (CC) The company or entity that performed the analyses. (DD) The analytical techniques or methods used. (EE) The results of such analyses. (FF) The operating conditions as existing at the time of sampling or

measurement.

These records shall be physically present or electronically accessible at the source location for a minimum of three (3) years. The records may be stored elsewhere for the remaining two (2) years as long as they are available upon request. If the Commissioner makes a request for records to the Permittee, the Permittee shall furnish the records to the Commissioner within a reasonable time.

(b) Unless otherwise specified in this permit, for all record keeping requirements not already legally required, the Permittee shall be allowed up to ninety (90) days from the date of permit issuance or the date of initial start-up, whichever is later, to begin such record keeping.

C.17 General Reporting Requirements [326 IAC 2-7-5(3)(C)] [326 IAC 2-1.1-11] (a) The Permittee shall submit the attached Quarterly Deviation and Compliance Monitoring

Report or its equivalent. Proper notice submittal under Section B –Emergency Provisions satisfies the reporting requirements of this paragraph. Any deviation from permit requirements, the date(s) of each deviation, the cause of the deviation, and the response steps taken must be reported except that a deviation required to be reported pursuant to an applicable requirement that exists independent of this permit, shall be reported according to the schedule stated in the applicable requirement and does not need to be included in this report. This report shall be submitted not later than thirty (30) days after the end of the reporting period. The Quarterly Deviation and Compliance Monitoring Report shall include a certification that meets the requirements of 326 IAC 2-7-6(1) by a "responsible official" as defined by 326 IAC 2-7-1(35). A deviation is an exceedance of a permit limitation or a failure to comply with a requirement of the permit.

(b) The address for report submittal is: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251


(c) Unless otherwise specified in this permit, any notice, report, or other submission required

by this permit shall be considered timely if the date postmarked on the envelope or certified mail receipt, or affixed by the shipper on the private shipping receipt, is on or before the date it is due. If the document is submitted by any other means, it shall be considered timely if received by IDEM, OAQ on or before the date it is due.

(d) Reporting periods are based on calendar years, unless otherwise specified in this permit.

For the purpose of this permit “calendar year” means the twelve (12) month period from January 1 to December 31 inclusive.

Stratospheric Ozone Protection

C.18 Compliance with 40 CFR 82 and 326 IAC 22-1 Pursuant to 40 CFR 82 (Protection of Stratospheric Ozone), Subpart F, except as provided for motor vehicle air conditioners in Subpart B, the Permittee shall comply with applicable standards for recycling and emissions reduction.


SECTION D.1 EMISSIONS UNIT OPERATION CONDITIONS

Emissions Unit Description: (a) One (1) Fuel Test Cell, identified as EU-04 LDTC4, constructed in 2008, with a maximum



Emission Unit ID


Maximum Capacity

Fuel Type


EU-01 LDTC1

1974 or prior

500 HP


none

Stack 1 EU-02 LDTC2 500 HP Stack 2 EU-03 LDTC3 500 HP Stack 3 EU-05 LDTC5 500 HP Stack 5 EU-06 LDTC6 500 HP Stack 6 EU-07 LDTC7 500 HP Stack 7 EU-08 LDTC8 500 HP Stack 8

(c) Five (5) Production Test Cells, consisting of the following:

Emission Unit

Description Date of

Construction Maximum Capacity Fuel Type Control Device

(ID) Stack ID

EU-09 LDD1

2008

450 HP Diesel,

Biodiesel, or JP-8

none

Stack 9 EU-10 LDD2 450 HP Stack 10 EU-11 LDD3 450 HP Stack 11 EU-12 LDD4 450 HP Stack 12 EU-17 LDD5 2014 500 HP Stack 17


Emission Unit ID


Type Control Device

(ID) Stack ID

EU-13

2008

142.86 HP Diesel, Biodiesel, or JP-8

none

Stack 13 EU-14 142.86 HP Stack 14 EU-15 142.86 HP Stack 15 EU-16 142.86 HP Stack 16

(e) Four (4) Hot Test Cells, consisting of the following:

Emission Unit ID


Type Control Device

(ID) Stack ID

EU-18 LDTC9

2014

500 HP Diesel, Biodiesel, or JP-8

none

Stack 18 EU-19 LDTC10 500 HP Stack 19 EU-20 LDTC11 500 HP Stack 20 EU-21 LDTC12 500 HP Stack 21

(f) One (1) Containerized Test Cell, identified as EU-22 LDD6, capable of testing with diesel,

biodiesel, JP-8, natural gas, or gasoline, constructed in 2018 and approved in 2019 for modification, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22.



Emission Unit ID



Control Device

(ID) Stack ID


construction


none Stack 23

EU-24 EMC2 1500 HP Stack 24 (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

Emission Limitations and Standards [326 IAC 2-7-5(1)] D.1.1 Prevention of Significant Deterioration (PSD) Minor Limits [326 IAC 2-2]

In order to render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable, the Permittee shall comply with the following: (a) The total NOx emissions from the following twenty-four (24) Test Cells shall not exceed

182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3 EU-05 LDTC5 EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4 EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-18 LDTC9 EU-19 LDTC10 EU-20 LDTC11 EU-21 LDTC12 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

(b) The total CO emissions from the following twenty-four (24) Test Cells shall not exceed

182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3 EU-05 LDTC5


Emission Unit ID EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4 EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-18 LDTC9 EU-19 LDTC10 EU-20 LDTC11 EU-21 LDTC12 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

Compliance with these limits in combination with potential to emit NOx and CO from all other emission units at this source, shall limit the source-wide potential to emit NOx and CO to less than 250 tons per year, each, and shall render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable.

D.1.2 BACT Avoidance Limit [326 IAC 8-1-6] In order to render the requirements of 326 IAC 8-1-6 not applicable, the VOC emissions from the Containerized Test Cell (EU-22 LDD6) shall not exceed 25 tons per twelve consecutive month period, with compliance determined at the end of each month. Compliance with this limit shall limit the VOC emissions from the Containerized Test Cell (EU-22 LDD6) to less than twenty-five (25) tons per year and shall render the requirements of 326 IAC 8-1-6 not applicable.

D.1.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] A Preventative Maintenance Plan is required for these facilities. Section B - Preventive Maintenance Plan contains the Permittee's obligation with regard to the preventive maintenance plan required by this condition.

Compliance Determination Requirements [326 IAC 2-7-5(1)][326 IAC 2-7-6(1)] D.1.4 Compliance Determination

(a) In order to determine compliance with the PSD Minor Limit in Condtion D.1.1(a), the NOx emissions from the twenty-four (24) Test Cells shall be calculated using the following equation:

𝑁𝑁𝑁𝑁𝑁𝑁 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 (𝑡𝑡𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑡𝑡ℎ

) = �(𝐷𝐷 𝑁𝑁 𝐸𝐸𝐸𝐸𝐷𝐷) + (𝐵𝐵 𝑁𝑁 𝐸𝐸𝐸𝐸𝐵𝐵) + (𝐽𝐽 𝑁𝑁 𝐸𝐸𝐸𝐸𝐽𝐽) + (𝑁𝑁 𝑁𝑁 𝐸𝐸𝐸𝐸𝑁𝑁) + (𝐺𝐺 𝑁𝑁 𝐸𝐸𝐸𝐸𝐺𝐺)

2000 𝑙𝑙𝑙𝑙𝐸𝐸𝑡𝑡𝐸𝐸𝐸𝐸

Where:

D = Diesel Fuel Usage (gal/month) EFD = NOx emission factor for diesel fuel combustion = 0.297 (lb/gal) B = Biodiesel Fuel Usage (gal/month)


EFB = NOx emission factor for biodiesel fuel combustion = 0.273 (lb/gal) J = JP-8 Fuel Usage (gal/month) EFJ = NOx emission factor for JP-8 fuel combustion = 0.293 (lb/gal) N = Natural Gas Usage (mmcf/month) EFN = NOx emission factor for natural gas combustion = 4161.60 (lb/mmcf) G = Gasoline Usage (gal/month) EFG = NOx emission factor for gasoline combustion = 0.212 (lb/gal)

(b) In order to determine compliance with the PSD Minor Limit in Condtion D.1.1(b), the CO

emissions from the twenty-four (24) Test Cells shall be calculated using the following equation:

𝐶𝐶𝑁𝑁 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 ( 𝑡𝑡𝑡𝑡𝑡𝑡𝑡𝑡

𝑚𝑚𝑡𝑡𝑡𝑡𝑡𝑡ℎ) = ∑ (𝐷𝐷 𝑥𝑥 𝐸𝐸𝐸𝐸𝐷𝐷)+(𝐵𝐵 𝑥𝑥 𝐸𝐸𝐸𝐸𝐵𝐵)+(𝐽𝐽 𝑥𝑥 𝐸𝐸𝐸𝐸𝐽𝐽)+(𝑁𝑁 𝑥𝑥 𝐸𝐸𝐸𝐸𝑁𝑁)+ (𝐺𝐺 𝑥𝑥 𝐸𝐸𝐸𝐸𝐺𝐺)

2000𝑙𝑙𝑙𝑙𝑙𝑙𝑡𝑡𝑡𝑡𝑡𝑡 +

∑ (𝐷𝐷1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐷𝐷1)+(𝐵𝐵1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐵𝐵1)+(𝐽𝐽1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐽𝐽1)

2000𝑙𝑙𝑙𝑙𝐸𝐸𝑡𝑡𝐸𝐸𝐸𝐸

Where: For Test Cells > 600 HP:

D = Diesel Fuel Usage (gal/month) EFD = CO emission factor for diesel fuel combustion = 0.116 lb/gal B = Biodiesel Fuel Usage (gal/month) EFB = CO emission factor for biodiesel fuel combustion = 0.107 lb/gal J = JP-8 Fuel Usage (gal/month) EFJ = CO emission factor for JP-8 fuel combustion = 0.115 lb/gal N = Natural Gas Usage (mmcf/month) EFN = CO emission factor for natural gas combustion = 568.14 lb/mmcf G = Gasoline Usage (gal/month) EFG = CO emission factor for gasoline combustion = 0.129 lb/gal

For Test Cells < 600 HP:

D1 = Diesel Fuel Usage (gal/month) EFD1 = CO emission factor for diesel fuel combustion = 0.130 lb/gal B1 = Biodiesel Fuel Usage (gal/month) EFB1 = CO emission factor for biodiesel fuel combustion = 0.120 lb/gal J1 = JP-8 Fuel Usage (gal/month) EFJ1 = CO emission factor for JP-8 fuel combustion = 0.128 lb/gal

(c) In order to determine compliance with the BACT Avoidance Limit in Condition D.1.2, the VOC emissions from Containerized Test Cell (EU-22 LDD6) shall be calculated using the following equation:

VOC Emissions (tons

month) = �

(D x EFD) + (B x EFB) + (J x EFJ) + ( x EF ) + (N x EFN)

2000 lbston

Where: D = Diesel Fuel Usage (gal/month) EFD = VOC emission factor for diesel fuel combustion = 0.012 lb/gal B = Biodiesel Fuel Usage (gal/month) EFB = VOC emission factor for biodiesel fuel combustion = 0.011 lb/gal J = JP-8 Fuel Usage (gal/month) EFJ = VOC emission factor for JP-8 fuel combustion = 0.012 lb/gal G = Gasoline Usage (gal/month) EFG = VOC emission factor for gasoline combustion = 0.394 lb/gal N = Natural Gas Usage (mmcf/month)


EFN = VOC emission factor for natural gas combustion = 120.36 lb/mmcf

Record Keeping and Reporting Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-19] D.1.5 Record Keeping Requirement

(a) To document the compliance status with Conditions D.1.1 and D.1.2, the Permittee shall maintain records in accordance with (1) and (8) below. Records maintained for (1) and (8) shall be taken monthly and shall be complete and sufficient to establish compliance with the PSD Minor Limit established in Condition D.1.1 and the BACT Avoidance Limit established in Condition D.1.2.

(1) The amount of Diesel Fuel used in each of the twenty-four (24) Test Cells (in

gallons) each month. (2) The amount of Biodiesel Fuel used in each of the twenty-four (24) Test Cells (in

gallons) each month. (3) The amount of JP-8 Fuel used in each of the twenty-four (24) Test Cells (in

gallons) each month. (4) The amount of Natural Gas used in each of the following Test Cells (in mmcf)

each month:

EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

(5) The amount of Gasoline Fuel used in Test Cell EU-22 LDD6, (in gallons) each

month. (6) The total NOx emissions each month and each compliance period calculated

using the equation in Condition D.1.4(a). (7) The total CO emissions each month and each compliance period calculated

using the equation in Condition D.1.4(b). (8) The total VOC emissions each month and each compliance period calculated

using the equation in Condition D.1.4(c).

(b) Section C - General Record Keeping Requirements contains the Permittee's obligations with regard to the record keeping required by this condition.

D.1.6 Reporting Requirements

A quarterly summary of the information to document the compliance status with Conditions D.1.1 and D1.2 shall be submitted using the reporting forms located at the end of this permit, or its equivalent, not later than thirty (30) days following the end of each calendar quarter. The report submitted by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a “responsible official” as defined by 326 IAC 2-7-1 (35). Section C - General Reporting Requirements contains the Permittee's obligations with regard to the reporting required by this condition.



Emissions Unit Description: Specifically Regulated Insignificant Activities (b) Sixteen (16) Natural Gas-fired Boilers, consisting of the following:


Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack ID













Boiler Lochinvar 1 2009 2.075 none B1 Boiler Lochinvar 2 2009 2.075 none B1 Boiler Lochinvar 3 2009 2.075 none B1 Boiler Lochinvar 4 2009 2.075 none B1 Boiler Lochinvar 5 2019* 0.400 none L5 Boiler Lochinvar 6 2019* 0.400 none L6 Boiler Lochinvar 7 2019* 0.400 none L7 Boiler Lochinvar 8 2019* 0.400 none L8 Boiler Lochinvar 9 2019* 0.400 none L9




* approved in 2019 for construction (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)


Emission Limitations and Standards [326 IAC 2-7-5(1)] D.2.1 Particulate Emissions [326 IAC 6-2-4]

Pursuant to 326 IAC 6-2-4 (Particulate Emission Limitations for Sources of Indirect Heating), the particulate emissions from each of the following units shall be less than the particulate emissions limitation (Pt) in pounds per MMBtu heat input, as follows:

Emission Unit Unit ID Particulate Emissions

Limitation (Pt) (lb/MMBtu) Hot Water Boiler Raypak-61 Boiler 1

0.60

Hot Water Boiler Raypak-61 Boiler 2 Hot Water Boiler Raypak-61 Boiler 3 Hot Water Boiler Aerco 96 Boiler 1 Hot Water Boiler Aerco 96 Boiler 2 Hot Water Boiler Aerco 96 Boiler 3 Hot Water Boiler Aerco 96 Boiler 4 Boiler Raypak-72 Boiler 1 0.59 Boiler Raypak-72 Boiler 2 Boiler Lochinvar 1

0.48

Boiler Lochinvar 2 Boiler Lochinvar 3 Boiler Lochinvar 4 Vertical-fired Tube Steam Boiler B1 Vertical-fired Tube Steam Boiler B2 Boiler Raypak-72 Boiler 3 0.47 Boiler Cleaver Brooks 1

0.46

Boiler Cleaver Brooks 2 Boiler Cleaver Brooks 3 Boiler Lochinvar 5 Boiler Lochinvar 6 Boiler Lochinvar 7 Boiler Lochinvar 8 Boiler Lochinvar 9

D.2.2 Preventive Maintenance Plan [326 IAC 2-7-5(12)]

A Preventative Maintenance Plan is required for these facilities. Section B - Preventive Maintenance Plan contains the Permittee's obligation with regard to the preventive maintenance plan required by this condition.



Emissions Unit Description: Specifically Regulated Insignificant Activities (c) Degreasing operations that do not exceed 145 gallons per 12 months, except if subject to

326 IAC 20-6. (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

Emission Limitations and Standards [326 IAC 2-7-5(1)] D.3.1 Cold Cleaner Degreaser Control Equipment and Operating Requirements [326 IAC 8-3-2]

Pursuant to 326 IAC 8-3-2 (Cold Cleaner Degreaser Control Equipment and Operating Requirements), the Permittee shall: (a) Ensure the following control equipment and operating requirements are met:

(1) Equip the degreaser with a cover. (2) Equip the degreaser with a device for draining cleaned parts. (3) Close the degreaser cover whenever parts are not being handled in the

degreaser. (4) Drain cleaned parts for at least fifteen (15) seconds or until dripping ceases; (5) Provide a permanent, conspicuous label that lists the operating requirements in

subdivisions (3), (4), (6), and (7). (6) Store waste solvent only in closed containers. (7) Prohibit the disposal or transfer of waste solvent in such a manner that could

allow greater than twenty percent (20%) of the waste solvent (by weight) to evaporate into the atmosphere.

(b) Ensure the following additional control equipment and operating requirements are met:

(1) Equip the degreaser with one (1) of the following control devices if the solvent is heated to a temperature of greater than forty-eight and nine-tenths (48.9) degrees Celsius (one hundred twenty (120) degrees Fahrenheit):

(A) A freeboard that attains a freeboard ratio of seventy-five hundredths

(0.75) or greater. (B) A water cover when solvent used is insoluble in, and heavier than, water. (C) A refrigerated chiller. (D) Carbon adsorption. (E) An alternative system of demonstrated equivalent or better control as

those outlined in clauses (A) through (D) that is approved by the department. An alternative system shall be submitted to the U.S. EPA as a SIP revision.

(2) Ensure the degreaser cover is designed so that it can be easily operated with

one (1) hand if the solvent is agitated or heated.


(3) If used, solvent spray:

(A) must be a solid, fluid stream; and (B) shall be applied at a pressure that does not cause excessive splashing.

D.3.2 Material Requirements for Cold Cleaner Degreasers [326 IAC 8-3-8]

Pursuant to 326 IAC 8-3-8 (Material Requirements for Cold Cleaner Degreasers), the Permittee shall not operate a cold cleaning degreaser with a solvent that has a VOC composite partial vapor pressure that exceeds one (1) millimeter of mercury (nineteen-thousandths (0.019) pound per square inch) measured at twenty (20) degrees Celsius (sixty-eight (68) degrees Fahrenheit).

D.3.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)] A Preventive Maintenance Plan is required for these facilities. Section B - Preventive Maintenance Plan contains the Permittee's obligation with regard to the preventive maintenance plan required by this condition.

Record Keeping and Reporting Requirement [326 IAC 2-7-19] D.3.4 Record Keeping Requirements

(a) To document the compliance status with Condition D.3.2, the Permittee shall maintain the following records for each purchase of solvent used in the cold cleaner degreasing operations. These records shall be retained on-site or accessible electronically for the most recent three (3) year period and shall be reasonably accessible for an additional two (2) year period.

(1) The name and address of the solvent supplier. (2) The date of purchase (or invoice/bill dates of contract servicer indicating service

date). (3) The type of solvent purchased. (4) The total volume of the solvent purchased. (5) The true vapor pressure of the solvent measured in millimeters of mercury at

twenty (20) degrees Celsius (sixty-eight (68) degrees Fahrenheit). (b) Section C - General Record Keeping Requirements contains the Permittee's obligations

with regard to the records required by this condition.


SECTION E.1 NSPS

Emissions Unit Description: Specifically Regulated Insignificant Activities (a) Three (3) Emergency Generators, consisting of the following:

Emission Unit

Description Emission

Unit ID Date of

Construction Maximum Capacity Control Device

(ID) Stack

ID

Diesel-fired Emergency Generator

Genset 1 1999 380 HP

none outdoors

Diesel-fired Emergency Generator

Genset 2 2010 755 HP

Diesel-fired CEP Stationary Fire Pump

FP 1 2009 171 HP

[Under 40 CFR 63, Subpart ZZZZ, these are considered affected units.] [Under 40 CFR 60, Subpart IIII, Genset 2 and FP 1 are considered affected units.] (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

New Source Performance Standards (NSPS) Requirements [326 IAC 2-7-5(1)] E.1.1 General Provisions Relating to New Source Performance Standards [326 IAC 12-1] [40 CFR Part

60, Subpart A] (a) Pursuant to 40 CFR 60.1, the Permittee shall comply with the provisions of 40 CFR Part

60, Subpart A – General Provisions, which are incorporated by reference as 326 IAC 12-1, for the Diesel-fired CEP Stationary Fire Pump, identified as FP 1, and the Diesel-fired Emergency Generator, identified as Genset 2, except as otherwise specified in 40 CFR Part 60, Subpart IIII.

(b) Pursuant to 40 CFR 60.4, the Permittee shall submit all required notifications and reports

to:

Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251

E.1.2 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines

NSPS [326 IAC 12] [40 CFR Part 60, Subpart IIII] (a) The Permittee shall comply with the following provisions of 40 CFR Part 60, Subpart IIII

(included as Attachment A to the operating permit), which are incorporated by reference as 326 IAC 12, for the Diesel-fired CEP Stationary Fire Pump, identified as FP 1:

(1) 40 CFR 60.4200(a)(2), (a)(3), and (b) (2) 40 CFR 60.4205(c) (3) 40 CFR 60.4206 (4) 40 CFR 60.4207(b)


(5) 40 CFR 60.4208 (6) 40 CFR 60.4209(a) (7) 40 CFR 60.4211(a), (b), (f)(1), (f)(2)(i), and (g) (8) 40 CFR 60.4212 (9) 40 CFR 60.4218 (10) 40 CFR 60.4219 (11) Tables 4 and 8 to Subpart IIII

(b) The Permittee shall comply with the following provisions of 40 CFR Part 60, Subpart IIII

(included as Attachment A to the operating permit), which are incorporated by reference as 326 IAC 12, for the Diesel-fired Emergency Generator, identified as Genset 2:

(1) 40 CFR 60.4200(a)(2)(i) (2) 40 CFR 60.4202(a)(2) (3) 40 CFR 60.4205(b) (4) 40 CFR 60.4206 (5) 40 CFR 60.4207(b) (6) 40 CFR 60.4208 (7) 40 CFR 60.4209(a) (8) 40 CFR 60.4211(a), (c), (f)(1), (f)(2)(i), and (g) (9) 40 CFR 60.4212 (10) 40 CFR 60.4214(b) (11) 40 CFR 60.4218 (12) 40 CFR 60.4219 (13) Table 8 to Subpart IIII

Emission Limitations and Standards [326 IAC 2-7-5(1)] E.1.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)]

A Preventive Maintenance Plan is required for these facilities. Section B - Preventive Maintenance Plan contains the Permittee's obligation with regard to the preventive maintenance plan required by this condition.


SECTION E.2 NESHAP

Emissions Unit Description: Specifically Regulated Insignificant Activities (a) Three (3) Emergency Generators, consisting of the following:


Emission Unit ID


Maximum Capacity

Control Device

(ID) Stack ID

Diesel-fired Emergency Generator Genset 1 1999 380 HP

none outdoors Diesel-fired Emergency Generator Genset 2 2010 755 HP

Diesel-fired CEP Stationary Fire Pump FP 1 2009 171 HP

[Under 40 CFR 63, Subpart ZZZZ, these are considered affected units.] [Under 40 CFR 60, Subpart IIII, Genset 2 and FP 1 are considered affected units.] (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

National Emission Standards for Hazardous Air Pollutants (NESHAP) Requirements [326 IAC 2-7-5(1)] E.2.1 General Provisions Relating to National Emission Standards for Hazardous Air Pollutants under

40 CFR Part 63 [326 IAC 20-1] [40 CFR Part 63, Subpart A] (a) Pursuant to 40 CFR 63.1 the Permittee shall comply with the provisions of 40 CFR Part

63, Subpart A – General Provisions, which are incorporated by reference as 326 IAC 20-1, for the emission unit(s) listed above, except as otherwise specified in 40 CFR Part 63, Subpart ZZZZ.

(b) Pursuant to 40 CFR 63.10, the Permittee shall submit all required notifications and

reports to:

Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251

E.2.2 Stationary Reciprocating Internal Combustion Engines NESHAP [40 CFR Part 63, Subpart ZZZZ] [326 IAC 20-82] The Permittee shall comply with the following provisions of 40 CFR Part 63, Subpart ZZZZ (included as Attachment B to the operating permit). which are incorporated by reference as 326 IAC 20-82, for the emission unit(s) listed above: (a) Genset 1:

(1) 40 CFR 63.6580 (2) 40 CFR 63.6585 (3) 40 CFR 63.6590(a)(1)(iii) and (iv) (4) 40 CFR 63.6595(a)(1), (b), and (c) (5) 40 CFR 63.6603(a)


(6) 40 CFR 63.6605 (7) 40 CFR 63.6625(e)(3), (f), (h), and (i) (8) 40 CFR 63.6640(a), (e), (f)(1), f(2)(i) (9) 40 CFR 63.6645(a)(5) (10) 40 CFR 63.6655(e) and (f)(2) (11) 40 CFR 63.6660 (12) 40 CFR 63.6665 (13) 40 CFR 63.6670 (14) 40 CFR 63.6675 (15) Table 2d (item 4) to Subpart ZZZZ (16) Table 6 (item 9) to Subpart ZZZZ (17) Table 8 to Subpart ZZZZ

(b) Genset 2 and FP 1:

(1) 40 CFR 63.6580 (2) 40 CFR 63.6585 (3) 40 CFR 63.6590(a)(2)(iii) and (c)(1) (4) 40 CFR 63.6595(a)(7) (5) 40 CFR 63.6665 (6) 40 CFR 63.6670 (7) 40 CFR 63.6675

Emission Limitations and Standards [326 IAC 2-7-5(1)] E.2.3 Preventive Maintenance Plan [326 IAC 2-7-5(12)]

A Preventive Maintenance Plan is required for these facilities. Section B - Preventive Maintenance Plan contains the Permittee's obligation with regard to the preventive maintenance plan required by this condition.


INDIANA DEPARTMENT OF ENVIRONMENTAL MANAGEMENT

OFFICE OF AIR QUALITY COMPLIANCE AND ENFORCEMENT BRANCH

PART 70 OPERATING PERMIT

CERTIFICATION Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015

This certification shall be included when submitting monitoring, testing reports/results or other documents as required by this permit.

Please check what document is being certified: Annual Compliance Certification Letter Test Result (specify) . Report (specify) . Notification (specify) . Affidavit (specify) . Other (specify) .

I certify that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete.

Signature:

Printed Name:

Title/Position:

Phone:

Date:




100 North Senate Avenue MC 61-53 IGCN 1003

Indianapolis, Indiana 46204-2251 Phone: (317) 233-0178

Fax: (317) 233-6865


EMERGENCY OCCURRENCE REPORT Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 This form consists of 2 pages Page 1 of 2

This is an emergency as defined in 326 IAC 2-7-1(12) • The Permittee must notify the Office of Air Quality (OAQ), within four (4) daytime

business hours (1-800-451-6027 or 317-233-0178, ask for Compliance Section); and • The Permittee must submit notice in writing or by facsimile within two (2) working days

(Facsimile Number: 317-233-6865), and follow the other requirements of 326 IAC 2-7-16.

If any of the following are not applicable, mark N/A

Facility/Equipment/Operation:

Control Equipment:

Permit Condition or Operation Limitation in Permit:

Description of the Emergency:

Describe the cause of the Emergency:


If any of the following are not applicable, mark N/A Page 2 of 2

Date/Time Emergency started:

Date/Time Emergency was corrected:

Was the facility being properly operated at the time of the emergency? Y N

Type of Pollutants Emitted: TSP, PM-10, SO2, VOC, NOX, CO, Pb, other:

Estimated amount of pollutant(s) emitted during emergency:

Describe the steps taken to mitigate the problem:

Describe the corrective actions/response steps taken:

Describe the measures taken to minimize emissions:

If applicable, describe the reasons why continued operation of the facilities are necessary to prevent imminent injury to persons, severe damage to equipment, substantial loss of capital investment, or loss of product or raw materials of substantial economic value:

Form Completed by: Title / Position: Date: Phone:




Part 70 Quarterly Report Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 Facility: Twenty-four (24) Test Cells, identified as EU-04 LDTC4, EU-01 LDTC1, EU-03

LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2

Parameter: NOx Emissions Limit: The total NOx emissions from the above mentioned twenty-four (24) Test Cells

shall not exceed 182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month.

QUARTER : YEAR:

Month NOx Emissions

(tons) NOx Emissions

(tons) NOx Emissions

(tons) This Month Previous 11 Months 12 Month Total

No deviation occurred in this quarter.

Deviation/s occurred in this quarter. Deviation has been reported on: .

Submitted by: Title / Position: Signature: Date: Phone:




Part 70 Quarterly Report Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 Facility: Twenty-four (24) Test Cells, identified as EU-04 LDTC4, EU-01 LDTC1, EU-03

LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2

Parameter: CO Emissions Limit: The total CO emissions from the above mentioned twenty-four (24) Test Cells

shall not exceed 182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month.

QUARTER : YEAR:

Month CO Emissions

(tons) CO Emissions (tons) CO Emissions (tons)

This Month Previous 11 Months 12 Month Total







Part 70 Quarterly Report Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 Facility: EU-22 LDD6 Parameter: VOC Emissions Limit: VOC emissions from the above mentioned Test Cell shall not exceed 25 tons per

twelve (12) consecutive month period, with compliance determined at the end of each month.

QUARTER : YEAR:

Month VOC Emissions

(tons) VOC Emissions

(tons) VOC Emissions

(tons) This Month Previous 11 Months 12 Month Total








QUARTERLY DEVIATION AND COMPLIANCE MONITORING REPORT Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015

Months: to Year:

Page 1 of 2

This report shall be submitted quarterly based on a calendar year. Proper notice submittal under Section B –Emergency Provisions satisfies the reporting requirements of paragraph (a) of Section C-General Reporting. Any deviation from the requirements of this permit, the date(s) of each deviation, the probable cause of the deviation, and the response steps taken must be reported. A deviation required to be reported pursuant to an applicable requirement that exists independent of the permit, shall be reported according to the schedule stated in the applicable requirement and does not need to be included in this report. Additional pages may be attached if necessary. If no deviations occurred, please specify in the box marked "No deviations occurred this reporting period".

NO DEVIATIONS OCCURRED THIS REPORTING PERIOD.

THE FOLLOWING DEVIATIONS OCCURRED THIS REPORTING PERIOD

Permit Requirement (specify permit condition #)

Date of Deviation:

Duration of Deviation:

Number of Deviations:

Probable Cause of Deviation:

Response Steps Taken:


Date of Deviation:






Page 2 of 2


Date of Deviation:






Date of Deviation:






Date of Deviation:





Form Completed by: Title / Position: Date: Phone:

Indiana Department of Environmental Management Office of Air Quality

Addendum to the Technical Support Document (ATSD) for a

Part 70 Significant Source Modification and Significant Permit Modification

Source Background and Description

Source Name: Cummins, Inc. Columbus Engine Plant (CEP) Source Location: 500 Central Avenue, Columbus, Indiana 47201 County: Bartholomew SIC Code: 3519 (Internal Combustion Engines, Not Elsewhere

Classified) Operation Permit No.: T005-39514-00015 Operation Permit Issuance Date: May 29, 2018 Significant Source Modification No.: 005-41279-00015 Significant Permit Modification No.: 005-41384-00015 Permit Reviewer: Iryn Calilung

Permitting History of Proposed Modification

On March 29, 2019, Cummins, Inc. Columbus Engine Plant (CEP) submitted an application to IDEM, OAQ relating to the following proposed modification: (a) to construct two (2) new test cells, capable of testing with 5 different types of fuel (diesel,

biodiesel, JP-8, natural gas, or gasoline), (b) to construct eight (8) new natural gas fired boilers, (c) to construct two (2) new machining operations, (d) to modify one (1) test cell for additional engine testing capabilities. This test cell was permitted in

2018 for testing with diesel, biodiesel, and JP-8. The additional capability is for testing with natural gas and gasoline.

(e) to itemize the maximum capacities of the seven (7) Diesel Cycle Test Cells. On June 12, 2019, CEP was provided a draft permit and supporting documents based on the proposed modification. This is a courtesy review of the permit prior to public notice, which is part of OAQ’s permitting review process. On August 16, 2019, after the application was submitted, CEP informed OAQ that the proposed modification has change. CEP no longer plans to operate gasoline in the 2 new test cells. Instead, the 2 new test cells would only operate engines burning diesel, biodiesel, JP-8, and natural gas On August 28, 2019, the Office of Air Quality (OAQ) had a notice posted on IDEM’s website (https://www.in.gov/idem/5474.htm), stating that Cummins, Inc. Columbus Engine Plant (CEP) had applied for a Title V Significant Source Modification and Significant Permit Modification to construct new test cells, boilers, and machining operations as well as modify the operation of an existing test cell to include testing gasoline engines. The notice also stated that the OAQ proposed to issue a Title V Significant Source Modification and Significant Permit Modification for this operation and provided information on how the public could review the proposed permit and other documentation. Finally, the notice informed interested parties that there was a period of thirty (30) days to provide comments on whether or not this permit should be issued as proposed.


Columbus Engine Plant (CEP) Page 2 of 10 Columbus, Indiana ATSD for SSM No. 005-41279-00015 Permit Reviewer: Iryn Calilung ATSD for SPM No. 005-41384-00015 On September 26, 2019, Bernie Paul, consultant for CEP, submitted comments to IDEM, OAQ on the draft Part 70 SSM No. 005-41279-00015 and Part 70 SPM No. 005-41384-00015. The comments submitted by CEP resulted in significant changes to the draft permit, in particular, the establishment of enforceable permit terms which restrict VOC emissions from Test Cell EU-22 LDD6 to render 326 IAC 8-1-6 not applicable. Due to these significant changes, the Part 70 SSM No. 005-41279-00015 and Part 70 SPM No. 005-41384-00015 had to be re-public notice and re-open the public comment period for 30 additional days. On September 27, 2019, the 30-day public comment period for these permits ended.

Comments and Responses

The Technical Support Document (TSD) is used by IDEM, OAQ for historical purposes. IDEM, OAQ does not make any changes to the original TSD, but the Permit will have the updated changes. The comments and revised permit language are provided below with deleted language as strikeouts and new language bolded. Below are the summary of the comments regarding the draft permits and supporting documents: Comment 1: Fuel Type for EU-23 EMC1 and EU-24 EMC2

Cummins has identified the following typographical changes which should be made to the permit documents. In the “Fuel Type” column of item (g) in Section D.1 of the draft permit for the two new test cells, Emission Units EU-23 EMC1 and EU-24 EMC2, the description includes “Diesel, Biodiesel, JP-8, Natural gas, or Gasoline”. This is incorrect. These test cells are not being permitted to operate engines burning gasoline. The Fuel Type column should be revised to state only “Diesel, Biodiesel, JP-8, or Natural gas”. A similar error occurs in the Technical Support Document (TSD) in the “Description of Proposed Modification” where these test cells are initially described. In Condition D.1.4(a)(5) of the draft permit, the permit requires CEP to keep records of the amount of Gasoline Fuel used in test cells EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2. This is incorrect. Test cells EU-23 EMC1 and EU-24 EMC2 are not being permitted to operate engines using gasoline as a fuel. The condition should be revised as follows: D.1.4(a)(5) The amount of Gasoline Fuel used in each of the Test Cells EU-22 LDD6, EU-23

EMC1, and EU-24 EMC2 (in gallons) each month. Response to Comment 1:

IDEM made the recommended changes to the draft permit.

Comment 2: Appendix A Emissions Calculations

Cummins has determined the Emission Calculations in Appendix A of the TSD contains errors and calculation methods Cummins does not agree with. The results of the errors also appear in the various emission summary tables in main part of the Technical Support Document. Cummins requests IDEM revise the Emission Calculations and the emission summary tables in the TSD.

Columbus Engine Plant (CEP) Page 3 of 10 Columbus, Indiana ATSD for SSM No. 005-41279-00015 Permit Reviewer: Iryn Calilung ATSD for SPM No. 005-41384-00015

Cummins has provided copies of the affected worksheets as an attachment to this letter. The affected worksheets include Notes which explain the necessary corrections and the affected cells in the worksheet are highlighted in yellow. The errors identified by CEP and the recommended emission calculation methods are described in greater detail below.

Comment 2(a): Summary of Modification Worksheet

The Summary of Modification worksheet (TSD Appendix A, Page 2 of 12) includes an error for the modified emission unit EU-22 LDD6. Under the heading of “PTE Before Control of the Modified Emission Units”, the PTE values for “PTE After Modification” and “PTE Increase for the Modification” are incorrect. CEP believes the cell references in this worksheet for PTE After Modification are incorrect, which leads to other errors in the emissions data. The PTE After Modification cells should reference the Large Test Cells Worksheet, EU-22 LDD6 Worst Case Emissions. It appears these cells currently reference the Large Test Cells Worksheet, EU-24 EMC2 Worst Case Emissions. The single highest HAP value for the Total Increase in PTE of the Modified Units and the Total PTE of the Modification should be 4.72 ton/yr, not 4.74 ton/year. In addition, CEP requests IDEM revise the wording/description of some cells which are shown in the attachment.

Response to Comment 2(a):

IDEM made the recommended changes to the emissions calculations worksheets. Comment 2(b): HAPs Summary Test Cells Worksheet

(1) In the HAPs Summary Test Cells worksheet, IDEM does not cite the source of the emission factors which are used. It appears the emission factors for natural gas engines and diesel engines are from AP-42 sections 3.2, 3.3, and 3.4, which are the appropriate emission factors to use.

(2) The emission factors for gasoline-fired engines, however, are not from AP-42. In CEP’s

permit application, it was proposed using the AP-42 Table 3.3-1 emission factor for “aldehydes” as an emission factor to represent either the maximum formaldehyde or acetaldehyde emission factor (with care given to not sum the two since the AP-42 factor applies to aldehydes in general and not each aldehyde individually). There are no other AP-42 emission factors for HAP emissions from gasoline engines.

Instead of using the AP-42 emission factors provided by CEP in its application, IDEM appears to have used a hybrid of the AP-42 emissions factor for VOC emissions from gasoline engines (expressed in lb of VOC/MMBtu of fuel burned) with speciated HAPs emissions data taken from US EPA’s SPECIATE database to create new emission factors for a variety of HAPs (SPECIATE expresses the HAPs data in terms of percentage of an individual HAP compared to the mass of total organic substances measured). This approach is not cited in the TSD, but Cummins was able to piece this information from prior communication with IDEM on this topic. Cummins has significant reservations about IDEM using this approach to determine potential to emit of HAPs from operating gasoline fired engines in Test Cell EU-22 LDD6. There are multiple technical issues with this approach.


Utilizing data points from two completely different data sets and multiplying them together to develop an emission factor creates significant uncertainty in the results. For example, the types of engines tested when developing the AP-42 VOC emission factor 25 to 30 years ago and the types of engines tested to establish the relative percentages of different organic species in gasoline engine exhaust in 2008 could be completely different and have significantly different emissions profiles. Although there is a basic logical appeal to apply the species percentages to the AP-42 VOC emission factor, it could lead to significant errors in the overall emission estimates. It is highly likely the AP-42 emission factor for VOCs highly overestimates the VOC emissions from modern gasoline engines. The test data which forms the basis for the AP-42 VOC emission factor is anywhere from 25 to 40 years old. It in no way reflects the emissions performance of current engine models which are now designed for greater fuel efficiency and emissions performance, both of which would lead to lower VOC emissions. If EPA developed a new VOC emission factor for gasoline engines based on current technologies, that emission factor would likely be significantly lower. Applying the SPECIATE percentages to a much lower VOC emission factor would provide more realistic estimates of HAP emissions. It could also be that the percentage of different HAPs might change as the performance of the engines improved over time. In addition, the testing which was conducted to establish the AP-42 VOC emission factor most likely used a measurement method intended to measure total VOC. It does not appear, however, that the SPECIATE data from which the various HAP percentages were established actually measured total VOC. Instead many different non-HAP and HAP organics were measured, and the HAP percentages were developed as a fraction of the measured individual HAP compared to the sum of all the measured compounds – not a measurement of total VOC. It’s not clear how many VOCs were not measured and what impact that might have had on the percentage each HAP compound comprised of the total. Furthermore, there are many different data points in the SPECIATE data. IDEM selected one category of data – “Gasoline Exhaust - Tier 2 light-duty vehicles using 0% Ethanol - Composite Profile" (2008)”. A different data set within SPECIATE may have notable differences in the various HAP percentages. IDEM does not explain why it selected the specific data set within SPECIATE.

Finally, the SPECIATE data was designed to develop broad emissions inventories for areas rather than emission factors for discrete engines in the context of a permitting action. Cummins appreciates IDEM’s efforts to use more detailed information in effort to develop more accurate estimates of HAP emissions. We believe this issue merits further discussion about whether the SPECIATE data used by IDEM, or other data represents the appropriate information for more accurate HAP emissions estimates. At this time, however, Cummins believes it is prudent to use the AP-42 emission factors until the use of the SPECIATE data can be explored and understood.

For these reasons, Cummins requests that IDEM use AP-42 emission factors to estimate HAP emissions, as proposed by Cummins in the permit application for this project.

Response to Comment 2(b):

IDEM made the recommended changes to the HAP emissions calculation worksheets.

Comment 2(c): Internal Combustion EF Worksheet


The Internal Combustion EF worksheet is a compilation of all the criteria pollutant emission factors used in estimating PTE for the engine test cells and emergency generators at the site. Cummins requests IDEM change two emission factors on this worksheet, which will have the impact of changing PTE values on the affected worksheets.

(1) PM EF

The first factor which should be changed is the PM emission factor for diesel engines > 600 hp. IDEM used 0.100 lb/MMBtu, which is an AP-42 emission factor from AP-42 Table 3.4-1. Cummins believes this emission factor includes both condensable and filterable forms of particulate matter. In Indiana, however, particulate matter is only the filterable form. Instead of using the PM emission factor from AP-42 Table 3.4-1, Cummins requests IDEM use the “Total Filterable Particulate” emission factor from AP-42 Table 3.4-2. This is a more accurate representation of the filterable particulate matter which should be used to estimate PM emissions.

(2) CO EF

The second factor which should be changed is the CO emission factor for natural gas engines. The CO for natural gas combustion should be 568.14 lb CO/MMSCF. IDEM used 0.317 lb CO/MMBtu from AP-42 Table 3.2-2. This emission factor is for engines operating at > 90% of its operating capacity. Cummins believes IDEM should use the emission factor of 0.557 lb CO/MMBtu for engines operating at < 90% capacity since the engines will likely operate at less than 90% capacity in a significant portion of the tests and it results in a higher PTE for natural gas combustion in these test cells. Changing this emission factor in this worksheet changes it in the Large Test Cells worksheet since the emission factors in that worksheet are linked to the emission factors in the Internal Combustion EF worksheet.

Response to Comment 2(c):

(1) The PM emission factor in AP-42 Table 3.4-1 is the more accurate representation to determine the potential emissions. It has also been the emission factor used for Cummins in previous permitting determinations. This AP-42 emissions factor does not indicate that it includes both filterable and condensable forms of particulate. In addition, it has a rating of B, compared to the AP-42 emission factor in Table 3.4-2, which has a rating of E (based on a single test).

(2) IDEM made the recommended changes to the emissions calculation worksheet.

Comment 2(d): Large Test Cells Worksheet

(1) In the Large Test Cell worksheet, the heading for the top table should be changed from “Diesel-fired Test Cell > 600 HP” to “Test Cells with Engines > 600 HP”. All the test cells on this page are permitted to operate with engines burning multiple fuels, not just diesel fuels, so the heading should be changed to reflect the correct terminology.

(2) In addition, there is an error in the maximum hourly output for test cell EU-24 EMC2 for

when burning natural gas. The value in the worksheet is listed as “1501 HP”. The correct value is “1500 HP”. Cummins requests IDEM revise the emission calculations with the correct horsepower value for this unit.

Columbus Engine Plant (CEP) Page 6 of 10 Columbus, Indiana ATSD for SSM No. 005-41279-00015 Permit Reviewer: Iryn Calilung ATSD for SPM No. 005-41384-00015 Response to Comment 2(d):



Comment 2(e): Small Test Cells Worksheet

(1) In the Small Test Cell worksheet, the heading for the top table should be changed from “Diesel-fired Test Cell < 600 HP” to “Test Cells with Engines < 600 HP”. All the test cells on this page are permitted to operate with engines burning multiple fuels, not just diesel fuel, so the heading should be changed to reflect the correct terminology.

(2) The Small Test Cells worksheet contains an error regarding the number of test cells with

capacity of 500 horsepower and the number of test cells with the capacity of 450 horsepower. There are 13 (not 12) test cells with capacity of 500 hp and 4 (not 5) test cells with capacity of 450 horsepower. The values in this spreadsheet should be revised to reflect these correct values.

(3) In addition, this worksheet includes a line of emission factors for gasoline as a potential

fuel. This line should be removed from the worksheet because these test cells are not permitted to operate engines burning gasoline.

Response to Comment 2(e):

(1) IDEM made the recommended changes to the emissions calculation worksheet. (2) IDEM made the recommended changes to the emissions calculation worksheet. (3) IDEM made the recommended changes to the emissions calculation worksheet.

Comment 3: Summary Tables

As a result of the requested changes described in the previous section, the various emissions summary tables in the Technical Support Document should be revised based on the corrections and updated emission calculations.

In addition, in the section of the TSD titled “Permit Level Determination – Part 70 Modification to an Existing Source”, Cummins requests IDEM correct the Total HAPs values for the new boilers Lochinvar 5-9 and Cleaver Brooks 1-3. The total HAP values of 0.75 ton/yr for each of the Lochinvar boilers and 1.17 ton/year for each of the Cleaver Brooks boilers is not correct. Those values should be changed to 0.003 ton/yr for the Lochinvar Boilers and 0.005 ton/yr for the Cleaver Brooks Boilers, as shown in the HAPs Summary Boilers and Emer G worksheet.

Response to Comment 3:

Due to changes made to the calculations, the tables in the original TSD are replaced by these following tables. In addition. The TSD Appendix A is replaced by the ATSD Appendix A, which reflects the updated calculations.


Comment 4: VOC Limit for Test Cell EU-22 LDD6

Cummins has proposed to modify Test Cell EU-22 LDD6 so it can operate engines which are burning gasoline. Because this change causes the unlimited potential to emit VOCs from the test cell to greater than 25 tons per year, which would invoke the VOC BACT requirements of 326 IAC 8-1-6, Cummins requested IDEM include an emission limit of 25 tons per 12 consecutive month period for Test Cell EU-22 LDD6. Although such a term was present in the applicant review drafts of the permit documents, the requested term is not present in the public noticed versions of SSM 41279 and SPM 41384. Without this term 326 IAC 8-1-6 VOC BACT would be an applicable requirement for Test Cell EU-22 LDD6. Cummins requests IDEM include a 25 ton per 12 consecutive month VOC limit for EU-22 LDD6 and the necessary compliance determination method, record keeping requirements, and reporting requirements. Cummins proposes the language below in bold to establish this limit and associated requirements.

First, a new section D.1.2 should be added to the permit. D.1.2 BACT Avoidance Limit [326 IAC 8-1-6] In order to render the requirements of 326 IAC 8-1-6 not applicable, the VOC emissions from the Containerized Test Cell (EU-22 LDD6) shall not exceed 25 tons per twelve consecutive month period, with compliance determined at the end of each month. Compliance with this limit shall limit the VOC emissions from the Containerized Test Cell (EU-22 LDD6) to less than twenty-five (25) tons per year and shall render the requirements of 326 IAC 8-1-6 not applicable. The sections which follow D.1.2 should be renumbered accordingly. Next, a compliance determination method should be added to what is currently Condition D.1.3 (but would be re-numbered to D.1.4). In order to determine compliance with the BACT Avoidance Limit in Condition D.1.2, the VOC emissions from Containerized Test Cell (EU-22 LDD6) shall be calculated using the following equation:

Unlimited PTE of the New Emission Units (tons/yr)Emission Unit PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPsElectronic Engine Test Cells EU-23-EMC1 1.85 1.06 1.03 0.94 75.68 2.19 15.77 0.979 Formaldehyde 1.33

EU-24-EMC2 4.60 2.64 2.56 2.32 187.64 5.43 39.09 2.428 Formaldehyde 3.30

Boilers Lochinvar 5 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003Lochinvar 6 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003Lochinvar 7 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003Lochinvar 8 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003Lochinvar 9 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003Cleaver Brooks 1 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 Hexane 0.005Cleaver Brooks 2 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 Hexane 0.005Cleaver Brooks 3 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 Hexane 0.005

Heavy Duty Machining Operation HDM-01 0 0 0 0 0 1.66 0 0.00 0.00HDM-02 0 0 0 0 0 1.66 0 0.00 0.00

Total Unlimited PTE of the New Units 6.49 3.82 3.71 3.27 264.98 11.02 56.25 3.41 Formaldehyde 4.66

Unlimited PTE Increase of the Modified Emission Units (tons/yr)Emission Unit PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPsContainerized Test Cell EU-22 LDD6Unlimited PTE Before Modification 2.07 1.19 1.15 1.05 44.87 1.86 17.59 0.016 Benzene 0.03Unlimited PTE After Modification 2.07 2.07 2.07 1.74 84.44 62.71 20.49 1.45 Toluene 1.48Unlimited PTE Increase for the Modification 0.00 0.88 0.92 0.69 39.57 60.84 2.90 1.43 Toluene 1.45

PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPsTotal PTE of the New Emission Units 6.49 3.82 3.71 3.27 264.98 11.02 56.25 3.41 Formaldehyde 4.66Total Increase in PTE of the Modified Emission Units 0.00 0.88 0.92 0.69 39.57 60.84 2.90 1.43 Toluene 1.45Total PTE of the Modification 6.49 4.71 4.63 3.96 304.55 71.86 59.15 1.43 Toluene 6.11


𝐕𝐕𝐕𝐕𝐕𝐕 𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄 (𝐭𝐭𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐄𝐭𝐭𝐦𝐦

) = �(𝐃𝐃 𝐱𝐱 𝐄𝐄𝐄𝐄𝐃𝐃) + (𝐁𝐁 𝐱𝐱 𝐄𝐄𝐄𝐄𝐁𝐁) + (𝐉𝐉 𝐱𝐱 𝐄𝐄𝐄𝐄𝐉𝐉) + (𝐆𝐆 𝐱𝐱 𝐄𝐄𝐄𝐄𝐆𝐆) + (𝐍𝐍 𝐱𝐱 𝐄𝐄𝐄𝐄𝐍𝐍)

𝟐𝟐𝟐𝟐𝟐𝟐𝟐𝟐 𝐥𝐥𝐥𝐥𝐄𝐄𝐭𝐭𝐄𝐄𝐄𝐄

Where: D = Diesel Fuel Usage (gal/month) EFD =VOC emission factor for diesel fuel combustion = 0.012 lb/gal B = Biodiesel Fuel Usage (gal/month) EFB =VOC emission factor for biodiesel fuel combustion = 0.011 lb/gal J = JP-8 Fuel Usage (gal/month) EFJ =VOC emission factor for JP-8 fuel combustion = 0.012 lb/gal G = Gasoline Usage (gal/month) EFG =VOC emission factor for gasoline combustion = 0.394 lb/gal N = Natural Gas Usage (mmcf/month) EFN =VOC emission factor for natural gas combustion = 120.36 lb/mmcf

A record keeping provision does not need to be added to the permit because the public noticed version of the permit already includes a record keeping requirement for gasoline usage in Test Cell EU-22 LDD6 in Condition D.1.5(a)(5) (with suggested amendments already discussed above). A reporting requirement should be added to Condition D.1.6 (which would be re-numbered to D.1.7) by editing the Condition so it reads as follows:

D.1.6 Reporting Requirements A quarterly summary of the information to document the compliance status with Condition D.1.1 and D.1.2 shall be submitted using the reporting forms located at the end of this permit, or its equivalent, not later than thirty (30) days following the end of each calendar quarter. The report submitted by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a “responsible official” as defined by 326 IAC 2-7-1 (35). Section C - General Reporting Requirements contains the Permittee's obligations with regard to the reporting required by this condition. A reporting form should also be added to the permit.

Response to Comment 4:

IDEM made the recommended changes to the permit.

Comment 5: CO Emissions Limit

The permit includes an emission limit and associated requirements to limit CO emissions from all the test cells so that entire source is minor for all PSD regulated pollutants. These requirements are included in Conditions D.1.1(b), D.1.3(b), and D.1.6. Cummins requests IDEM delete these requirements from the permit because although the unlimited PTE of CO emissions from the site are greater than 250 tons/year, the CO limit is not needed to limit PTE of CO at the source. The permit already includes a limit on NOx emissions from the test cells in Condition D.1.1. The limit is 182 tons per year for all 24 test cells. Because of this limit, it is physically impossible for the 24 test cells to emit more than 182 tons per year of CO. For every permutation of engine size and fuel used, CO emissions, on a per unit of fuel basis, are lower than the NOx emissions for that same scenario. This means that the test cells are not physically capable of emitting more than 182 tons per year of CO. Consequently, the CO emissions limit, the additional emission


calculations, the record keeping, and the reporting related to CO emissions in the permit are not necessary to limit CO. Cummins appreciates your consideration of these comments and requests IDEM revise the permit accordingly and issue corrective statements in an Addendum to the Technical Support Document. If IDEM disagrees with Cummins’ request, then the Compliance Determination equations for CO emissions in Condition D.1.3(b) should be revised. The emission factors should be revised to reflect the changes proposed by Cummins earlier in this document (CO for natural gas combustion should be 568.14 lb CO/MMSCF). In addition, since none of the test cells with engine capacities less than 600 hp are not permitted to use natural gas or gasoline, the compliance determination equations for CO from engines less than 600 hp in capacity should not include emissions from burning natural gas or gasoline. The equation should be modified as follows:

In order to determine compliance with the PSD Minor Limit in Condtion D.1.1(c), the CO emissions from the twenty-four (24) Test Cells shall be calculated using the following equation:

𝐶𝐶𝐶𝐶 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 ( 𝑡𝑡𝑡𝑡𝑡𝑡𝑡𝑡𝑚𝑚𝑡𝑡𝑡𝑡𝑡𝑡ℎ

) = ∑ (𝐷𝐷 𝑥𝑥 𝐸𝐸𝐸𝐸𝐷𝐷)+(𝐵𝐵 𝑥𝑥 𝐸𝐸𝐸𝐸𝐵𝐵)+(𝐽𝐽 𝑥𝑥 𝐸𝐸𝐸𝐸𝐽𝐽)+(𝑁𝑁 𝑥𝑥 𝐸𝐸𝐸𝐸𝑁𝑁)+ (𝐺𝐺 𝑥𝑥 𝐸𝐸𝐸𝐸𝐺𝐺)


∑ (𝐷𝐷1 𝑥𝑥 𝐸𝐸𝐸𝐸𝐷𝐷1)+(𝐵𝐵1 𝑥𝑥 𝐸𝐸𝐸𝐸𝐵𝐵1)+(𝐽𝐽1 𝑥𝑥 𝐸𝐸𝐸𝐸𝐽𝐽1)+(𝑁𝑁1 𝑥𝑥 𝐸𝐸𝐸𝐸𝑁𝑁1)+ (𝐺𝐺1 𝑥𝑥 𝐸𝐸𝐸𝐸𝐺𝐺1)

2000𝑙𝑙𝑙𝑙𝑙𝑙𝑡𝑡𝑡𝑡𝑡𝑡


... EFN = CO emission factor for natural gas combustion = 323.34

568.14 (lb/MMSCF) For Test Cells < 600 HP: ...

N = Natural Gas Usage (MMSCF/month) EFN = CO emission factor for natural gas combustion = (323.34 lb/MMSCF) G1 = Gasoline Usage (gal/month) EFG1 = CO emission factor for gasoline combustion = 0.129 (lb/gal)

... Response to Comment 5:

Due to the proposed modification, the source wide unlimited CO potential to emit is greater than 250 tons/year. To maintain the PSD minor source status of the source, the CO emissions have to limited to less than 250 tons/year. Limiting one pollutant, such as NOx in this case, does not federally enforce a limit for another pollutant, such as CO. In order to properly restrict potential to emit, limitations must be both federally enforceable and enforceable in a practical manner. The CO PSD minor limit and equation used to determine compliance have been revised. ... D.1.1(b) The total CO emissions from the following twenty-four (24) Test Cells shall not exceed

195 182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month:


...

IDEM Contact

(a) If you have any questions regarding this permit, please contact Iryn Calilung, Indiana Department Environmental Management, Office of Air Quality, Permits Branch, 100 North Senate Avenue, MC 61-53 IGCN 1003, Indianapolis, Indiana 46204-2251, or by telephone at (317) 233-5392 or (800) 451-6027, and ask for Iryn Calilung or (317) 233-5692.

(b) A copy of the findings is available on the Internet at: http://www.in.gov/ai/appfiles/idem-caats/ (c) For additional information about air permits and how the public and interested parties can

participate, refer to the IDEM Air Permits page on the Internet at: http://www.in.gov/idem/airquality/2356.htm; and the Citizens' Guide to IDEM on the Internet at: http://www.in.gov/idem/6900.htm.




Appendix A: Emission Calculations

Source Summary

Page 1 of 12 ATSD App A

Company Name: Cummins Inc. Columbus Engine Plant (CEP)

Address: 500 Central Avenue, Columbus, Indiana 47201

Permit No.: T005-39514-00015

Significant Source Modification No.: 005-41279-00015

Significant Permit Modification No.: 005-41384-00015

Permit Writer: Iryn Calilung

Unlimited Potential to Emit (tons/yr)PM PM10 PM2.5 SO2 NOx VOC CO Total HAPs Single Worst HAP

Test Cells 93.15 90.39 90.28 85.83 835.49 166.19 299.00 7.16 5.18 Formaldehyde

Boilers 0.23 0.93 0.93 0.07 12.20 0.67 10.25 0.23 0.22 Hexane

Heaters and Air Make-up Units 0.73 2.93 2.93 0.23 38.49 2.12 32.33 0.73 0.69 Hexane

Emergency Generators 0.44 0.38 0.38 0.37 8.80 0.31 1.96 0.73 0.22 Formaldehyde

Degreasers 0.00 0.00 0.00 0.00 0.00 0.60 0.00 0.00 0.00

Trimmers <1 <1 <1 0.00 0.00 0.00 0.00 0.00 0.00

Battery Assembly <1 <1 <1 0.00 0.00 <1 0.00 0.00 0.00

Grinding and Machining <1 <1 <1 0.00 0.00 3.31 0.00 0.00 0.00

VOC and HAP Storage Containers 0.00 0.00 0.00 0.00 0.00 1.01 0.00 <1 <1 Xylene

Cooling Towers 0.17 0.17 0.17 0.00 0.00 0.00 0.00 0.00 0.00

Welding 1.01 1.01 1.01 0.00 0.00 0.00 0.00 0.09 0.09 Mn

Paved Roads 8.83 1.77 0.43 0.00 0.00 0.00 0.00 0.00 0.00

Total 107.55 100.57 99.12 86.50 894.98 175.21 343.55 9.95 5.40 Formaldehyde

Limited Emissions (tons/yr)PM PM10 PM2.5 SO2 NOx VOC CO Total HAPs Single Worst HAP

Test Cells 93.15 90.39 90.28 85.83 182.00 166.19 < 182* 7.16 5.18 Formaldehyde


Boilers 0.73 2.93 2.93 0.23 38.49 2.12 32.33 0.73 0.69 Hexane


Degreasers 0.00 0.00 0.00 0.00 0.00 0.60 0.00 0.00 0.00

Trimmers <1 <1 <1 0.00 0.00 0.00 0.00 0.00 0.00

Battery Assembly <1 <1 <1 0.00 0.00 <1 0.00 0.00 0.00

Grinding and Machining <1 <1 <1 0.00 0.00 3.31 0.00 0.00 0.00

VOC and HAP Storage Containers 0.00 0.00 0.00 0.00 0.00 1.01 0.00 <1 <1 Xylene

Cooling Towers 0.17 0.17 0.17 0.00 0.00 0.00 0.00 0.00 0.00

Welding 1.01 1.01 1.01 0.00 0.00 0.00 0.00 0.09 0.09 Mn

Paved Roads 8.83 1.77 0.43 0.00 0.00 0.00 0.00 0.00 0.00

Total 107.55 100.57 99.12 86.50 241.49 175.21 226.54 9.95 5.40 Formaldehyde

* Limited CO to render 326 IAC 2-2 not applicable. This value is based on the determination that CO emissions will be less than the limited NOx PSD minor limit.


Summary of Modification




Permit No.: T005-39514-00015




Unlimited PTE of the New Emission Units (tons/yr)

Emission Unit PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPs

Electronic Engine Test Cells EU-23-EMC1 1.85 1.06 1.03 0.94 75.68 2.19 15.77 0.979 Formaldehyde 1.33


Boilers Lochinvar 5 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003

Lochinvar 6 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003




Cleaver Brooks 1 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 Hexane 0.005



Heavy Duty Machining Operation HDM-01 0 0 0 0 0 1.66 0 0.00 0.00

HDM-02 0 0 0 0 0 1.66 0 0.00 0.00

Total Unlimited PTE of the New Units 6.49 3.82 3.71 3.27 264.98 11.02 56.25 3.41 Formaldehyde 4.66

Unlimited PTE Increase of the Modified Emission Units (tons/yr)


Containerized Test Cell EU-22 LDD6

Unlimited PTE Before Modification 2.07 1.19 1.15 1.05 44.87 1.86 17.59 0.016 Benzene 0.03

Unlimited PTE After Modification 2.07 2.07 2.07 1.74 84.44 62.71 20.49 1.45 Toluene 1.48

Unlimited PTE Increase for the Modification 0.00 0.88 0.92 0.69 39.57 60.84 2.90 1.43 Toluene 1.45

PTE Increase Due to the Modification (tons/yr)

PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPs

Total PTE of the New Emission Units 6.49 3.82 3.71 3.27 264.98 11.02 56.25 3.41 Formaldehyde 4.66

Total Increase in PTE of the Modified Emission Units 0.00 0.88 0.92 0.69 39.57 60.84 2.90 1.43 Toluene 1.45

Total PTE of the Modification 6.49 4.71 4.63 3.96 304.55 71.86 59.15 1.43 Toluene 6.11


HAPs Summary Test Cells




Permit No.: T005-39514-00015




HAP Emission Factors

Benzene Toluene Xylene 1,3-Butadiene Formaldehyde Acetylaldehyde Acrolein PAH Biphenyl Methanol Hexane 2,2,4-Trimethylpentane

Diesel Fuel <600 lb/MMBtu 0.000933 0.000409 0.000285 0.000039 0.001180 0.000767 0.000093 0.000168

Diesel Fuel >600 lb/MMBtu 0.000776 0.000281 0.000193 0.000079 0.000025 0.000008 0.000168

Natural Gas lb/MMBtu 0.000440 0.000408 0.000184 0.000267 0.052800 0.008360 0.005140 0.000212 0.002500 0.001100 0.000250

Gasoline lb/MMBtu 0.07 0.07

Total HAPs

Diesel Fuel <600 lb/hp-hr 6.53E-06 2.86E-06 2.00E-06 2.74E-07 8.26E-06 5.37E-06 6.48E-07 1.18E-06 2.71E-05

Diesel Fuel >600 lb/hp-hr 5.43E-06 1.97E-06 1.35E-06 0.00E+00 5.52E-07 1.76E-07 5.53E-08 1.18E-06 1.07E-05

Natural Gas lb/hp-hr 3.08E-06 2.86E-06 1.29E-06 1.87E-06 3.70E-04 5.85E-05 3.60E-05 1.48E-06 1.75E-05 7.70E-06 1.75E-06 5.02E-04

Gasoline lb/hp-hr 4.90E-04 4.90E-04 4.90E-04

PTE (tons/yr) Total HAPs

EU-04 LDTC4 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-01 LDTC1 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-02 LDTC2 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-03 LDTC3 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-05 LDTC5 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-06 LDTC6 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-07 LDTC7 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-08 LDTC8 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-09 LDD1 450 HP 0.0129 0.0056 0.0039 0.0005 0.0163 0.0106 0.0013 0.0023 0.05

EU-10 LDD2 450 HP 0.0129 0.0056 0.0039 0.0005 0.0163 0.0106 0.0013 0.0023 0.05

EU-11 LDD3 450 HP 0.0129 0.0056 0.0039 0.0005 0.0163 0.0106 0.0013 0.0023 0.05

EU-12 LDD4 450 HP 0.0129 0.0056 0.0039 0.0005 0.0163 0.0106 0.0013 0.0023 0.05

EU-17 LDD5 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-13 142.86 HP 0.0041 0.0018 0.0012 0.0002 0.0052 0.0034 0.0004 0.0007 0.02

EU-14 142.86 HP 0.0041 0.0018 0.0012 0.0002 0.0052 0.0034 0.0004 0.0007 0.02

EU-15 142.86 HP 0.0041 0.0018 0.0012 0.0002 0.0052 0.0034 0.0004 0.0007 0.02

EU-16 142.86 HP 0.0041 0.0018 0.0012 0.0002 0.0052 0.0034 0.0004 0.0007 0.02

EU-18 LDTC9 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-19 LDTC10 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-20 LDTC11 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-21 LDTC12 500 HP 0.0143 0.0063 0.0044 0.0006 0.0181 0.0118 0.0014 0.0026 0.06

EU-22 LDD6 675 HP 0.0161 0.0084 0.0040 0.0055 1.4487 1.4487 0.1064 0.0035 0.0044 0.0517 0.0228 0.0052 1.48

EU-23-EMC1 605 HP 0.0144 0.0076 0.0036 0.0050 0.9794 0.1551 0.0953 0.0031 0.0039 0.0464 0.0204 0.0046 1.33

EU-24-EMC2 1500 HP 0.0357 0.0188 0.0089 0.0123 2.4283 0.3845 0.2364 0.0077 0.0097 0.1150 0.0506 0.0115 3.30

Total HAP Emissions 0.32 0.15 0.09 0.03 5.18 2.20 0.46 0.06 0.02 0.21 0.09 0.02 7.16

Assume that the HAP emissions for biodiesel and JP-8 are equivelent to the HAP emission factors for diesel fuel; therefore, the HAP emissions for these fuels does not affect the worst case HAP emissions.

To convert the lb/MMBtu emission factor to lb/hp-hr, multiply the emission factor by 0.007. (7000 Btu/hp-hr)

HAP PTE = Maximum Capcity (HP) x Emission Factor (lb/ hp-hr) x 8760 hrs/yr x 1 ton/ 2000 lbs

Formaldehyde is the single highest HAP.

HAP Emissions for EU-22 LDD6 prior to modification:

Benzene Toluene Xylene 1,3-Butadiene Formaldehyde Acetylaldehyde Acrolein PAH Total HAPs

EU-22 LDD6 1.61E-02 5.82E-03 3.99E-03 0.00E+00 1.63E-03 5.22E-04 1.63E-04 3.48E-03 3.17E-02


HAPs Summary Boilers and Emer G




Permit No.: T005-39514-00015




HAPs Emission - Entire Source

Pollutant Internal Combustion External Combustion Total HAPs (tons/yr)

<600 HP >600 HP < 99 MMBtu/hr BoilersHeaters and

AMUs

Emergency

GeneratorsBenzene 6.53E-06 lb/hp/hr 9.33E-04 lb/MMBtu/hr 5.43E-06 lb/hp-hr 2.1E-03 lb/MMCF 2.56E-04 8.08E-04 1.77E-01 1.78E-01 Benzene

Toluene 2.86E-06 lb/hp/hr 4.09E-04 lb/MMBtu/hr 1.97E-06 lb/hp-hr 3.4E-03 lb/MMCF 4.15E-04 1.31E-03 7.76E-02 7.93E-02 Toluene

Xylene 2.00E-06 lb/hp/hr 2.85E-04 lb/MMBtu/hr 1.35E-06 lb/hp-hr 5.41E-02 5.41E-02 Xylene

1,3-Butadiene 2.74E-07 lb/hp/hr 3.91E-05 lb/MMBtu/hr 7.42E-03 7.42E-03 1,3-Butadiene

Formaldehyde 8.26E-06 lb/hp/hr 1.18E-03 lb/MMBtu/hr 5.52E-07 lb/hp-hr 7.5E-02 lb/MMCF 9.15E-03 2.89E-02 2.24E-01 2.62E-01 Formaldehyde

Acetylaldehyde 5.37E-06 lb/hp/hr 7.67E-04 lb/MMBtu/hr 1.76E-07 lb/hp-hr 1.46E-01 1.46E-01 Acetylaldehyde

Acrolein 6.48E-07 lb/hp/hr 9.25E-05 lb/MMBtu/hr 5.52E-08 lb/hp-hr 1.75E-02 1.75E-02 Acrolein

PAH 1.18E-06 lb/hp/hr 1.68E-04 lb/MMBtu/hr 1.48E-06 lb/hp-hr 3.19E-02 3.19E-02 PAH

Dichlorobenzene 1.2E-03 lb/MMCF 1.46E-04 4.62E-04 6.08E-04 Dichlorobenzene

Hexane 1.8E+00 lb/MMCF 2.20E-01 6.93E-01 9.12E-01 Hexane

Lead 5.0E-04 lb/MMCF 6.10E-05 1.92E-04 2.53E-04 Lead

Cadmium 1.1E-03 lb/MMCF 1.34E-04 4.23E-04 5.58E-04 Cadmium

Chromium 1.4E-03 lb/MMCF 1.71E-04 5.39E-04 7.10E-04 Chromium

Manganese 3.8E-04 lb/MMCF 4.64E-05 1.46E-04 1.93E-04 Manganese

Nickel 2.1E-03 lb/MMCF 2.56E-04 8.08E-04 1.06E-03 Nickel

Total HAPs 0.23 0.73 0.73 1.69

Single Worst HAP 0.22 0.69 0.22 0.91

Hexane Hexane Formaldehyde Hexane

HAP PTE = Maximum Capcity x Emission Factor x 8760 hrs/yr x 1 ton/ 2000 lbs


Internal Combustion EF




Permit No.: T005-39514-00015




Sulfur Content (S): 0.05

Emission Factors for Emergency Generators and Test Cells

PM PM10 PM2.5 SO2 NOx VOC CO

Diesel 0.297 lb/gal

Site Specific Stack Test

Diesel <600 HP 0.002 lb/hp-hr 0.002 lb/hp-hr 0.002 lb/hp-hr 0.002 lb/hp-hr 0.031 lb/hp-hr 0.003 lb/hp-hr 0.007 lb/hp-hr

AP-42 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1

Diesel >600 HP 0.001 lb/hp-hr 0.0004 lb/hp-hr 0.0004 lb/hp-hr 0.0004 lb/hp-hr 0.024 lb/hp-hr 0.001 lb/hp-hr 0.006 lb/hp-hr


Gasoline Any 0.00021 lb/hp-hr 0.00021 lb/hp-hr 0.00021 lb/hp-hr 0.000591 lb/hp-hr 0.011 lb/hp-hr 0.0216 lb/hp-hr 0.00696 lb/hp-hr

AP-42 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1 Table 3.3-1

Diesel <600 HP 0.310 lb/MMBtu 0.310 lb/MMBtu 0.310 lb/MMBtu 0.290 lb/MMBtu - - 0.360 lb/MMBtu 0.950 lb/MMBtu


Diesel >600 HP 0.100 lb/MMBtu 0.057 lb/MMBtu 0.056 lb/MMBtu 0.051 lb/MMBtu - - 0.090 lb/MMBtu 0.850 lb/MMBtu


Natural Gas 0.0000771 lb/MMBtu 0.00999 lb/MMBtu 0.00999 lb/MMBtu 0.000588 lb/MMBtu 4.080 lb/MMBtu 0.118 lb/MMBtu 0.557 lb/MMBtu


Gasoline Any 0.10 lb/MMBtu 0.10 lb/MMBtu 0.10 lb/MMBtu 0.084 lb/MMBtu 1.63 lb/MMBtu 3.03 lb/MMBtu 0.99 lb/MMBtu


Diesel <600 HP 0.042 lb/gal 0.042 lb/gal 0.042 lb/gal 0.040 lb/gal - - 0.049 lb/gal 0.130 lb/gal

converted to lb/gal using HHV 0.137 MMBtu/gal

Diesel >600 HP 0.0137 lb/gal 0.00785 lb/gal 0.00762 lb/gal 0.00692 lb/gal - - 0.0123 lb/gal 0.116 lb/gal


Biodiesel <600 HP 0.039 lb/gal 0.039 lb/gal 0.039 lb/gal 0.037 lb/gal 0.273 lb/gal 0.045 lb/gal 0.120 lb/gal


Biodiesel >600 HP 0.013 lb/gal 0.007 lb/gal 0.007 lb/gal 0.0064 lb/gal 0.273 lb/gal 0.011 lb/gal 0.107 lb/gal


JP-8 <600 HP 0.042 lb/gal 0.042 lb/gal 0.042 lb/gal 0.039 lb/gal 0.293 lb/gal 0.049 lb/gal 0.128 lb/gal


JP-8 >600 HP 0.014 lb/gal 0.008 lb/gal 0.008 lb/gal 0.007 lb/gal 0.293 lb/gal 0.012 lb/gal 0.115 lb/gal


Natural Gas 0.08 lb/MMSCF 10.19 lb/MMSCF 10.19 lb/MMSCF 0.60 lb/MMSCF 4161.60 lb/MMSCF 120.36 lb/MMSCF 568.14 lb/MMSCF

Converted to lb/MMSCF using HHV 1020 MMBTU/MMSCF

Gasoline 0.013 lb/gal 0.013 lb/gal 0.013 lb/gal 0.01092 lb/gal 0.2119 lb/gal 0.3939 lb/gal 0.1287 lb/gal


Methodology:

The NOx emission factor (lb/gal) is based on stack testing performed by the source.

The first set of emission factors for diesel fired engines greater than 600 HP and less than 600 HP are from AP-42. Referneces to the Tables in which the emission factors

are listed can be found in the table under the emission factor.

The Biodiesel and JP-8 emission factors for NOx are converted from the stack testing results using the ratio of the High Heat Value for diesel and the High Heat Value for

either Biodiesel or JP-8 fuels. Emission Factor (lb/gal) = NOx Emission Factor for Diesel (lb/gal) * High Heat Value of Diesel (lb/gal) / High heat Value of JP-8 (lb/gal)

Emission Factor (lb/gal) = AP-42 Emission Factor (lb/MMBtu) * High Heat Value for Fuel (MMBtu/gal)

Emission Factor for SO2 (lb/MMBtu) = 1.01 x Sulfur Content (wt%)


Large Test Cells




Permit No.: T005-39514-00015


Significant Permit Modification No.: 005-41384-00015Permit Writer: Iryn Calilung

Test Cells with engines > 600 HP

Emission Factors PM PM10 PM2.5 SO2 NOx VOC CO Heat Content of Fuel

Diesel Fuel (lb/gal) 0.014 0.008 0.008 0.007 0.297 0.012 0.116 Diesel Fuel 0.137 (MMBtu/gal)

Bio Diesel (lb/gal) 0.013 0.007 0.007 0.006 0.273 0.011 0.107 Bio Diesel 0.126 (MMBtu/gal)

JP-8 (lb/gal) 0.014 0.008 0.008 0.007 0.293 0.011 0.115 JP-8 0.135 (MMBtu/gal)

Natural Gas (lb/MMSCF) 0.08 10.19 10.19 0.60 4161.60 120.36 568.14 Natural Gas 1020 (MMBtu/MMSCF)

Gasoline (lb/gal) 0.013 0.013 0.013 0.011 0.212 0.394 0.129 Gasoline 0.130 (MMBtu/gal)

Containerized Test CellMaximum Hourly

Output

Maximum Annual Fuel

UsagePotential Emissions (tons/yr)

EU-22 LDD6 PM PM10 PM2.5 SO2 NOx VOC CO

Diesel Fuel 675 HP 302124 gal/yr 2.07 1.19 1.15 1.05 44.87 1.86 17.52

Bio Diesel 675 HP 328500 gal/yr 2.07 1.19 1.15 1.05 44.87 1.86 17.59

JP-8 675 HP 306600 gal/yr 2.07 1.19 1.15 1.05 44.87 1.74 17.59

Natural Gas 675 HP 40.58 MMSCF/yr 0.002 0.21 0.21 0.01 84.44 2.44 11.53

Gasoline 675 HP 318392 gal/yr 2.07 2.07 2.07 1.74 33.73 62.71 20.49

Worst Case Emissions 2.07 2.07 2.07 1.74 84.44 62.71 20.49

Maximum Hourly

Output

Maximum Annual Fuel

Usage

Potential Emissions (tons/yr)

EU-23-EMC1 PM PM10 PM2.5 SO2 NOx VOC CO



JP-8 605 HP 274804 gal/yr 1.85 1.06 1.03 0.94 40.21 1.56 15.77



Maximum Hourly

Output

Maximum Annual Fuel

Usage





JP-8 1500 HP 681333 gal/yr 4.60 2.64 2.56 2.32 99.70 3.86 39.09



Methodology:

For liquid fuels:

Heat Content of Fuel (MMBtu/gal) = Heating Value (Btu/lb) * 1 MMBtu/ 1000000 Btu * Fuel Density (lb/gal)

Maximum Annual Fuel Usage (gal/yr) = Maximum Hourly Output (HP) x 7000 Btu/HP-hr x 1 MMBtu/ 1,000,000 Btu x 8760 hrs/yr ÷ Heat Content of Fuel (MMBtu/gal)

PTE (tons/yr) = Emission Factor (lb/gal) x Maximum Fuel Usage (gal/yr) x 1 ton/ 2000 lbs

For gasous fuels:

Heat Content of Fuel (MMBtu/MMSCF) = 1020 Btu/scf x 1 MMBtu/ 1000000 Btu x 1000000 scf/ MMSCF

PTE (tons/yr) = Emission Factor (lb/MMSCF) x Maximum Fuel Usage (MMSCF/yr) x 1 ton/ 2000 lbs

Electronics Engine Test

Cell


Cell


Small Test Cells




Permit No.: T005-39514-00015




Test Cells with Engines < 600 hp

Emission Factors (lb/gal) PM PM10 PM2.5 SO2 NOx VOC CO Heating Values (MMBtu/gal)

Diesel Fuel 0.042 0.042 0.042 0.04 0.297 0.049 0.13 Diesel Fuel 0.137

Bio Diesel 0.039 0.039 0.039 0.037 0.273 0.045 0.12 Bio Diesel 0.126

JP-8 0.042 0.042 0.042 0.039 0.293 0.049 0.128 JP-8 0.135

Maximum Hourly

Output

Maximum Annual Fuel



Diesel Fuel 500 HP 223795.6 gal/yr 4.70 4.70 4.70 4.48 33.23 5.48 14.55

Bio Diesel 500 HP 243333.3 gal/yr 4.75 4.75 4.75 4.50 33.22 5.48 14.60

JP-8 500 HP 227111.1 gal/yr 4.77 4.77 4.77 4.43 33.27 5.56 14.54

Worst Case Emissions, each 4.77 4.77 4.77 4.50 33.27 5.56 14.60

Worst Case Emissions, combined 13 Test Cell x 62.00 62.00 62.00 58.52 432.53 72.33 189.80

Cycle Test CellsMaximum Hourly

Output

Maximum Annual Fuel





JP-8 450 HP 204400 gal/yr 4.29 4.29 4.29 3.99 29.94 5.01 13.08



Cold Test CellsMaximum Hourly

Output

Maximum Annual Fuel



Diesel Fuel 142.86 HP 63942.88 gal/yr 1.34 1.34 1.34 1.28 9.50 1.57 4.16

Bio Diesel 142.86 HP 69525.2 gal/yr 1.36 1.36 1.36 1.29 9.49 1.56 4.17

JP-8 142.86 HP 64890.19 gal/yr 1.36 1.36 1.36 1.27 9.51 1.59 4.15



PTE = Emission Factor (lb/gal) x Maximum Annual Fuel Usage (gal/yr) x 1 ton/ 2000 lbs

The emissions for each individual cell are calculated in the table, the worse case emissions for each pollutants are multipled by the number of engines.

Fuel Test Cells,

Production Test Cells,

and Hot Test Cells


Boilers




Permit No.: T005-39514-00015




HHV (MMBtu/MMSCF) Maximum Emission Factors (lb/MMCF)

1020 Capacity PM PM10 PM2.5 SO2 NOx VOC CO

For Natural Gas (MMBtu/hr) 1.90 7.60 7.60 0.60 100 5.50 84

Emission Unit Emissions (tons/yr)

Vertical Fired Tube Steam Boiler

B1 2.100 0.02 0.07 0.07 0.01 0.90 0.05 0.76

B2 2.100 0.02 0.07 0.07 0.01 0.90 0.05 0.76

Hot Water Boiler

Raypak-61 Boiler 1 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Raypak-61 Boiler 2 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Raypak-61 Boiler 3 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Aerco 96 Boiler 1 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Aerco 96 Boiler 2 0.900 0.01 0.03 0.03 0.00 0.39 0.02 0.32

Aerco 96 Boiler 3 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Aerco 96 Boiler 4 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Boilers

Raypak-72 Boiler 1 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Raypak-72 Boiler 2 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Raypak-72 Boiler 3 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Lochinvar 1 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 2 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 3 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 4 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 5 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 6 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 7 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 8 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 9 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Cleaver Brooks 1 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

Cleaver Brooks 2 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

Cleaver Brooks 3 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

(MMBtu/hr) PM PM10 PM2.5 SO2 NOx VOC CO

Total 28.42 0.23 0.93 0.93 0.07 12.20 0.67 10.25

Methodology

*PM emission factor is filterable PM only. PM10 emission factor is filterable and condensable PM10 combined.

PM2.5 emission factor is filterable and condensable PM2.5 combined.

**Emission Factors for NOx: Uncontrolled = 100, Low NOx Burner = 50, Low NOx Burners/Flue gas recirculation = 32

All emission factors are based on normal firing.

MMBtu = 1,000,000 Btu

MMCF = 1,000,000 Cubic Feet of Gas

Emission Factors are from AP 42, Chapter 1.4, Tables 1.4-1, 1.4-2, 1.4-3, SCC #1-02-006-02, 1-01-006-02, 1-03-006-02, and 1-03-006-03

Potential Throughput (MMCF) = Heat Input Capacity (MMBtu/hr) x 8,760 hrs/yr x 1 MMCF/1,020 MMBtu

Emission (tons/yr) = Throughput (MMCF/yr) x Emission Factor (lb/MMCF)/2,000 lb/ton


Air Make Up Units




Permit No.: T005-39514-00015




Emission Unit Heat Input Emission Unit Heat Input Emission Unit Heat Input

Air Make Up Units (MMBtu/hr) B82 Dock Unit 1 0.320 Ventilation Inlet 1 0.823

AHAP 1 2.000 B82 Dock Unit 2 0.320 Ventilation Inlet 2 0.823



AHAP 4 2.000 B82 Dock Unit 5 0.320 Viking Chip 1 0.320



AHAP 7 2.000 CAU-LDTC 0.937 Viking Chip 4 0.320

AHAP 8 2.000 Cell Ventilation 1 0.550 Viking Dock 1 0.320



AHAP 11 1.000 Cell Ventilation 4 0.550 Viking Perimeter 1 0.160

AHAP 12 1.000 Cell Ventilation 5 Viking Perimeter 2 0.160

AHU Hybrid 0.800 Cell Ventilation 6 Viking Perimeter 3 0.160

AHU-N4A-42 1 0.557 Cell Ventilation 7 Viking Perimeter 4 0.160


B30 1 1.000 Cell Ventilation 9 Viking Perimeter 6 0.160




B30 RTU 0.090 electric DOC test rig 0.000 Viking Perimeter 10 0.160

B42 Unit 0.320 LDD 1 3.490 Viking Perimeter 11 0.160

B47 1.200 LDD 2 3.490 Viking Perimeter 12 0.160

B60 Dock Unit 1 0.320 LDD 3 3.490 Viking Perimeter 13 0.160






B72 Perimeter 1 0.160 LDD 9 2.670 Viking Perimeter 19 0.160

B72 Perimeter 2 0.160 LDD AHU 12 0.030 Viking Perimeter 20 0.160

B73 1 1.039 LDD RTU 10 0.020 Viking Perimeter 21 0.160


B73 3 1.039 Roll Up DR73 1 1.100 Viking Perimeter 23 0.160


B73 5 1.039 Roll Up DR73 3 1.100

B73 6 1.039 Roll Up DR73 4 1.100 Total Maximum Heat Input

B73 Conference 0.056 Roll Up DR73 5 1.100 89.633 MMBtu/hr

Summary of Potential Emissions from Sources of Natural Gas Combustion


Emission Factor

(lnb/MMCF)1.9 7.6 7.6 0.6 100 5.5 84

PTE (tons/yr) 0.73 2.93 2.93 0.23 38.49 2.12 32.33

Emission Factors are from AP 42, Chapter 1.4, Tables 1.4-1, 1.4-2, 1.4-3, SCC #1-02-006-02,

1-01-006-02, 1-03-006-02, and 1-03-006-03. Based on normal firing.

Potential Emissions (tons/yr) = Heat Input Capacity (MMBtu/hr) * 8760 hrs/yr *1 MMCF/ 1020 MMBtu

* Emission Factor (lb/MMSCF)/* 1 ton/ 2000lbs

2.700

2.700


Emergency Generators




Permit No.: T005-39514-00015




Potential to Emit (tons/yr)


Diesel-fired Emergency Generators

Genset 1 380 HP 0.21 0.21 0.21 0.20 2.95 0.07 0.64

Genset 2 755 HP 0.13 0.08 0.08 0.08 4.53 0.13 1.04

Diesel-fired Stationary Fire Pump Engines

CEP 171 HP 0.09 0.09 0.09 0.09 1.33 0.11 0.29

Total Emissions 0.44 0.38 0.38 0.37 8.80 0.31 1.96

Total Engine Output (HP) engines <600 HP 551 HP

Total Engine Output (HP) engines >600 HP 755 HP

Total Engine Power (MMBtu/hr) 0.00 MMBtu/hr

Methodology:

Potential Emissions (tons/yr) = Maximum Output (HP) * Internal Combustion Emission Factor (lb/hp-hr)

* 500 Operating hrs/yr * 1 ton/ 2000 lbs

Emission Factors are from AP-42 Chapter 3. See page 2 for detailed documentation.


Insignificant Activities




Permit No.: T005-39514-00015




DegreasersUsage Density VOC Content VOC

(gal/yr) (lb/gal) (wt%) (ton/yr)

Solvent 145 8.34 100% 0.60

TrimmersParticulate emissions from the trimmers are negligible.

Grinding and MachiningEmission Unit Usage Density VOC Content VOC PTE

HDM-01 500 gal/yr 7.84 lb/gal 84.5% (wt) 1.66 ton/yr


Methodology:

VOC PTE (tons/yr) = Usage (gal/yr) x Density (lb/gal) x VOC Content (wt%) x 1 ton/ 2000 lbs

The Grinding and Machining Operations use an aquous solution and mist collectors. Particulate emissions are negligible.

Cooling Towers

Emissions Unit

Circulation

Rate (gal/hr)Drift (%)

PM

Emission

s Factor

(lb/gal)

TDS (ppm)

PM

Emissions

(tons/yr)

PM10

Emmisions

(ton/yr)

PM2.5

Emmisions

(ton/yr)

Cooling Tower 162000 0.02 0.019 1500 0.17 0.17 0.17

Total 0.17 0.17 0.17

Methodology:

Potential Emissions (tons/yr) = Circulation Rate (gal/hr) * Drift (%) * Emission Factor (lb PM/ 10000 gal)

* TDS ratio (2000 ppm / 12000 ppm) *8760 hrs/yr * 1 ton/ 2000 lb

Emission Factor from AP-42, Table 13.4-1. Factors imply a TDS content of 12,000 ppm.

Drift (%) is the percentage of water droplets that become entrained in the cooling tower exit air stream.

PM = PM10 = PM2.5

WeldingEmission Factors PM PM10 PM2.5 Mn

(lb pollutant/ lb wire) 0.0055 0.0055 0.0055 0.0005

ID Maximum Capacity Potential Emissions (ton/yr)

TIG 19.5 lb wire/hr 0.47 0.47 0.47 0.04

MIG 11.25 lb wire/hr 0.27 0.27 0.27 0.02

MIG 11.25 lb wire/hr 0.27 0.27 0.27 0.02

Total 1.01 1.01 1.01 0.09

Mehodolgy:

Potential Emissions (tons/yr) = Max Capacity (lb/hr) * Emission Factor (lb/lb) * 8760 hrs/yr * 1 ton/ 2000 lb

Battery AssemblyPM, PM10, PM2.5, and VOC emissions from the Battery Assembly Operation are negligible.

Paint Booth

DensityVOC

Content

Solid

ContentUsage Rate PM PM10 PM2.5 VOC

(lb/gal) (wt%) (wt%) (gal/unit) (unit/hr) (tons/yr) (tons/yr) (tons/yr) (tons/yr)

Block Coating 8.91 4% 37% 0.4 0.3 0.86 0.86 0.86 0.20

Head Coating 8.91 4% 37% 0.2 0.3 0.43 0.43 0.43 0.10

Total Emissions 1.29 1.29 1.29 0.30

Emissions after control (dry filters) 99% control efficiency 0.01 0.01 0.01

Surface Coating Usage = 4.32 gallons/day VOC Emissions = 1.64 lbs/day

Metholdology:

Potential VOC Emissions (tons/yr) = Usage Rate (gal/hr) * Density (lb/gal) * VOC Content (wt%) * 1 ton/2000 lbs * 8760 hrs/yr

Potential PM Emissions (tons/yr) = Usage Rate (gal/hr) * Density (lb/gal) * Solid Content (wt%) * (1 - Transfer Efficiency (50%)

*1 ton/ 2000 lbs * 8760 hrs/yr

Fuel Storage Tanks Maximum Throughput (gallons/yr) VOC Working Losses VOC Emissions (tons/yr) Total (tpy)

Tank 2 15,800 gal x 54 turnovers 853200 9.23 0.005

Tank 5 15,800 gal x 50 turnovers 790000 0.09 0.00005 1.01



Other VOC and HAP Storage Containers VOC/HAP Emissions < 1

Methodology:

US EPA TANKS Version 4.09 PTE (tons/yr) = VOC Working Losses (lbs/yr) x 8760 hrs/yr x 1 ton/2000 lbs


Paved Roads




Permit No.: T005-39514-00015




The following calculations determine the amount of emissions created by paved roads, based on 8,760 hours of use and AP-42, Ch 13.2.1 (1/2011).

Vehicle Informtation (provided by source)

Type

Maximum

number of

vehicles per day

Number of one-

way trips per day

per vehicle

Maximum trips

per day (trip/day)

Maximum

Weight Loaded

(tons/trip)

Total Weight

driven per day

(ton/day)

Maximum one-

way distance

(feet/trip)

Maximum one-

way distance

(mi/trip)

Maximum one-

way miles

(miles/day)

Maximum one-

way miles

(miles/yr)

Vehicle (entering plant) (one-way trip) 5.0 1.0 5.0 40.0 200.0 10000 1.894 9.5 3456.4

Vehicle (leaving plant) (one-way trip) 5.0 1.0 5.0 20.0 100.0 10000 1.894 9.5 3456.4

Totals 10.0 300.0 18.9 6912.9

Average Vehicle Weight Per Trip = 30.0 tons/trip

Average Miles Per Trip = 1.89 miles/trip

Unmitigated Emission Factor, Ef = [k * (sL)^0.91 * (W)^1.02] (Equation 1 from AP-42 13.2.1)

PM PM10 PM2.5

where k = 0.011 0.0022 0.00054 lb/VMT = particle size multiplier (AP-42 Table 13.2.1-1)

W = 30.0 30.0 30.0 tons = average vehicle weight (provided by source)

sL = 9.7 9.7 9.7 g/m^2 = silt loading value for paved roads at iron and steel production facilities - Table 13.2.1-3)

Taking natural mitigation due to precipitation into consideration, Mitigated Emission Factor, Eext = E * [1 - (p/4N)] (Equation 2 from AP-42 13.2.1)

Mitigated Emission Factor, Eext = Ef * [1 - (p/4N)]

where p = 125 days of rain greater than or equal to 0.01 inches (see Fig. 13.2.1-2)

N = 365 days per year

PM PM10 PM2.5

Unmitigated Emission Factor, Ef = 2.793 0.559 0.1371 lb/mile

Mitigated Emission Factor, Eext = 2.554 0.511 0.1254 lb/mile

Dust Control Efficiency = 50% 50% 50% (pursuant to control measures outlined in fugitive dust control plan)

Process

Mitigated

PTE of PM

(Before Control)

(tons/yr)

Mitigated

PTE of PM10

(Before Control)

(tons/yr)

Mitigated

PTE of PM2.5

(Before Control)

(tons/yr)

Mitigated

PTE of PM

(After Control)

(tons/yr)

Mitigated

PTE of PM10

(After Control)

(tons/yr)

Mitigated

PTE of PM2.5

(After Control)

(tons/yr)

Vehicle (entering plant) (one-way trip) 4.41 0.88 0.22 2.21 0.44 0.11

Vehicle (leaving plant) (one-way trip) 4.41 0.88 0.22 2.21 0.44 0.11

Totals 8.83 1.77 0.43 4.41 0.88 0.22

Methodology Abbreviations

Total Weight driven per day (ton/day) = [Maximum Weight Loaded (tons/trip)] * [Maximum trips per day (trip/day)] PM = Particulate Matter

Maximum one-way distance (mi/trip) = [Maximum one-way distance (feet/trip) / [5280 ft/mile] PM10 = Particulate Matter (<10 um)

Maximum one-way miles (miles/day) = [Maximum trips per year (trip/day)] * [Maximum one-way distance (mi/trip)] PM2.5 = Particle Matter (<2.5 um)

Average Vehicle Weight Per Trip (ton/trip) = SUM[Total Weight driven per day (ton/day)] / SUM[Maximum trips per day (trip/day)] PTE = Potential to Emit

Average Miles Per Trip (miles/trip) = SUM[Maximum one-way miles (miles/day)] / SUM[Maximum trips per year (trip/day)]

Unmitigated PTE (tons/yr) = [Maximum one-way miles (miles/yr)] * [Unmitigated Emission Factor (lb/mile)] * (ton/2000 lbs)

Mitigated PTE (Before Control) (tons/yr) = [Maximum one-way miles (miles/yr)] * [Mitigated Emission Factor (lb/mile)] * (ton/2000 lbs)

Mitigated PTE (After Control) (tons/yr) = [Mitigated PTE (Before Control) (tons/yr)] * [1 - Dust Control Efficiency]

Indiana Department of Environmental Management Office of Air Quality

Technical Support Document (TSD) for a Part 70 Significant Source

Modification and Significant Permit Modification

Source Description and Location

Source Name: Cummins, Inc. Columbus Engine Plant (CEP) Source Location: 500 Central Avenue, Columbus, Indiana 47201 County: Bartholomew SIC Code: 3519 (Internal Combustion Engines, Not Elsewhere

Classified) Operation Permit No.: T005-39514-00015 Operation Permit Issuance Date: May 29, 2018 Significant Source Modification No.: 005-41279-00015 Significant Permit Modification No.: 005-41384-00015 Permit Reviewer: Sommer Cochran

Existing Approvals

The source was issued Part 70 Operating Permit Renewal No. 005-39514-00015 on May 29, 2018. There have been no subsequent approvals issued.

County Attainment Status

The source is located in Bartholomew County.

Pollutant Designation SO2 Better than national standards. CO Unclassifiable or attainment effective November 15, 1990. O3 Unclassifiable or attainment effective July 20, 2012, for the 2008 8-hour ozone standard.1

PM10 Unclassifiable effective November 15, 1990. PM2.5 Unclassifiable or attainment effective April 5, 2005, for the annual PM2.5 standard. PM2.5 Unclassifiable or attainment effective December 13, 2009, for the 24-hour PM2.5 standard. NO2 Cannot be classified or better than national standards. Pb Unclassifiable or attainment effective December 31, 2011.

1Unclassifiable or attainment effective October 18, 2000, for the 1-hour ozone standard which was revoked effective June 15, 2005. (a) Ozone Standards

Volatile organic compounds (VOC) and Nitrogen Oxides (NOx) are regulated under the Clean Air Act (CAA) for the purposes of attaining and maintaining the National Ambient Air Quality Standards (NAAQS) for ozone. Therefore, VOC and NOx emissions are considered when evaluating the rule applicability relating to ozone. Bartholomew County has been designated as attainment or unclassifiable for ozone. Therefore, VOC and NOx emissions were reviewed pursuant to the requirements for Prevention of Significant Deterioration (PSD), 326 IAC 2-2.

(b) PM2.5

Bartholomew County has been classified as attainment for PM2.5. Therefore, direct PM2.5, SO2, and NOx emissions were reviewed pursuant to the requirements for Prevention of Significant Deterioration (PSD), 326 IAC 2-2.

Cummins, Inc. Columbus Engine Plant (CEP) Page 2 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 (c) Other Criteria Pollutants

Bartholomew County has been classified as attainment or unclassifiable in Indiana for all the other criteria pollutants. Therefore, these emissions were reviewed pursuant to the requirements for Prevention of Significant Deterioration (PSD), 326 IAC 2-2.

Fugitive Emissions

Since this type of operation is not one (1) of the twenty-eight (28) listed source categories under 326 IAC 2-2-1(ff)(1), 326 IAC 2-3-2(g), or 326 IAC 2-7-1(22)(B), and there is no applicable New Source Performance Standard or National Emission Standard for Hazardous Air Pollutants that was in effect on August 7, 1980, fugitive emissions are not counted toward the determination of PSD, Emission Offset, and Part 70 Permit applicability. The fugitive emissions of hazardous air pollutants (HAP) are counted toward the determination of Part 70 Permit applicability and source status under Section 112 of the Clean Air Act (CAA).

Greenhouse Gas (GHG) Emissions

On June 23, 2014, in the case of Utility Air Regulatory Group v. EPA, cause no. 12-1146, (available at http://www.supremecourt.gov/opinions/13pdf/12-1146_4g18.pdf) the United States Supreme Court ruled that the U.S. EPA does not have the authority to treat greenhouse gases (GHGs) as an air pollutant for the purpose of determining operating permit applicability or PSD Major source status. On July 24, 2014, the U.S. EPA issued a memorandum to the Regional Administrators outlining next steps in permitting decisions in light of the Supreme Court’s decision. U.S. EPA’s guidance states that U.S. EPA will no longer require PSD or Title V permits for sources “previously classified as ‘Major’ based solely on greenhouse gas emissions.” The Indiana Environmental Rules Board adopted the GHG regulations required by U.S. EPA at 326 IAC 2-2-1(zz), pursuant to Ind. Code § 13-14-9-8(h) (Section 8 rulemaking). A rule, or part of a rule, adopted under Section 8 is automatically invalidated when the corresponding federal rule, or part of the rule, is invalidated. Due to the United States Supreme Court Ruling, IDEM, OAQ cannot consider GHG emissions to determine operating permit applicability or PSD applicability to a source or modification.

Source Status - Existing Source

The table below summarizes the potential to emit of the entire source, prior to the proposed modification, after consideration of all enforceable limits established in the effective permits. If the control equipment

http://www.supremecourt.gov/opinions/13pdf/12-1146_4g18.pdf

Cummins, Inc. Columbus Engine Plant (CEP) Page 3 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 has been determined to be integral, the table reflects the potential to emit (PTE) after consideration of the integral control device.

Source-Wide Emissions Prior to Modification (ton/year)

PM1 PM101 PM2.51, 2 SO2 NOX VOC CO Single HAP3

Total HAPs

Total PTE of Entire Source Excluding Fugitive Emissions*

67.74 62.53 61.16 49.69 240.00 67.05 217.94 3.92

(Formaldehyde)

14.78

Title V Major Source Thresholds NA 100 100 100 100 100 100 10 25

PSD Major Source Thresholds 250 250 250 250 250 250 250 -- --

1Under the Part 70 Permit program (40 CFR 70), PM10 and PM2.5, not particulate matter (PM), are each considered as a "regulated air pollutant.” 2PM2.5 listed is direct PM2.5. 3Single highest source-wide HAP *Fugitive HAP emissions are always included in the source-wide emissions.

(a) This existing source is not a major stationary source, under PSD (326 IAC 2-2), because no PSD

regulated pollutant is emitted at a rate of two hundred fifty (250) tons per year or more and it is not one of the twenty-eight (28) listed source categories, as specified in 326 IAC 2-2-1(ff)(1).

(b) This existing source is not a major source of HAP, as defined in 40 CFR 63.2, because HAP

emissions are less than ten (10) tons per year for any single HAP and less than twenty-five (25) tons per year of a combination of HAPs.

(c) These emissions are based on the TSD of Renewal No. 005-39514-00015, issued on May 29,

2018.

Description of Proposed Modification

The Office of Air Quality (OAQ) has reviewed an application, submitted by Cummins, Inc. Columbus Engine Plant (CEP) on March 29, 2019, relating to the following: (a) construction of two (2) new test cells, (b) construction of eight (8) new boilers, (c) construction of two (2) new machining operations, (d) modification of one (1) test cell for additional engine testing capabilities. This test cell was

permitted in 2018 for testing with diesel, biodiesel, and JP-8. The additional capability is for testing with natural gas and gasoline.

(e) to itemize the maximum capacities of the seven (7) Diesel Cycle Test Cells, The following is a list of the new and modified emission units and pollution control devices: (a) Two (2) Electronics Engine Test Cells, consisting of the following:

Cummins, Inc. Columbus Engine Plant (CEP) Page 4 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015

Emission Unit ID



Control Device

(ID) Stack ID

EU-23-EMC1 Approved in 2019 for

construction

605 HP Diesel, Biodiesel, JP-8, Natural gas, or

Gasoline

none

Stack 23

EU-24-EMC2 1500 HP Stack 24

(b) Eight (8) Natural Gas-fired Boilers, consisting of the following:


Emission Unit ID Date of Construction

Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack

ID

Boiler Cleaver Brooks 1 2019 0.62 none CB1 Boiler Cleaver Brooks 2 2019 0.62 none CB2 Boiler Cleaver Brooks 3 2019 0.62 none CB3 Boiler Lochinvar 5 2019 0.40 none L5 Boiler Lochinvar 6 2019 0.40 none L6 Boiler Lochinvar 7 2019 0.40 none L7 Boiler Lochinvar 8 2019 0.40 none L8 Boiler Lochinvar 9 2019 0.40 none L9

(c) Two (2) Heavy Duty Machining Operations, identified as HDM-01 and HDM-02, approved in 2019

for construction, with a maximum machining solution usage of 500 gallons per year each, using mist collectors for particulate control, and exhausting indoors.

(d) One (1) Containerized Test Cell, identified as EU-22 LDD6, capable of testing with diesel,

biodiesel, JP-8, natural gas, or gasoline, constructed in 2018, approved for modification in 2019, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22.

The maximum capacities of the following has been itemized:


Emission Unit ID


Maximum Capacity

Fuel Type


EU-01 LDTC1

1974 or prior

25.46 MMBtu/hr 500 HP

(combined) Diesel,

Biodiesel, or JP-8

none

Stack 1

EU-02 LDTC2 500 HP Stack 2 EU-03 LDTC3 500 HP Stack 3 EU-05 LDTC5 500 HP Stack 5 EU-06 LDTC6 500 HP Stack 6 EU-07 LDTC7 500 HP Stack 7 EU-08 LDTC8 500 HP Stack 8

The seven (7) Cycle Test Cells have a combined maximum capacity of 25.46 MMBtu/hr. This is equivalent to 500 HP each. Therefore, there is no increase in emissions and no modification of the emission units.

Enforcement Issues

There are no pending enforcement actions related to this modification.


Emission Calculations

See Appendix A of this Technical Support Document for detailed emission calculations.

Permit Level Determination – Part 70 Modification to an Existing Source

Pursuant to 326 IAC 2-1.1-1(12), Potential to Emit is defined as “the maximum capacity of a stationary source or emission unit to emit any air pollutant under its physical and operational design. Any physical or operational limitation on the capacity of a source to emit an air pollutant, including air pollution control equipment and restrictions on hours of operation or type or amount of material combusted, stored, or processed shall be treated as part of its design if the limitation is enforceable by the U. S. EPA, IDEM, or the appropriate local air pollution control agency.” The following table is used to determine the appropriate permit level under 326 IAC 2-7-10.5. This table reflects the PTE before controls. If the control equipment has been determined to be integral, the table reflects the potential to emit (PTE) after consideration of the integral control device.

PTE Before Controls of the New Emission Units (ton/year)

Process / Emission Unit PM PM10 PM2.51 SO2 NOX VOC CO Single

HAP2 Total HAPs

Electronic Test Cells EU-23-EMC1 1.92 1.10 1.10 0.96 75.68 2.19 15.80 0.98 1.33 EU-24-EMC2 4.77 2.73 2.73 2.38 187.76 5.43 39.18 2.43 3.30 Boilers Lochinvar 5 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 0.75 Lochinvar 6 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 0.75 Lochinvar 7 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 0.75 Lochinvar 8 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 0.75 Lochinvar 9 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 0.75 Cleaver Brooks 1 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 1.17 Cleaver Brooks 2 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 1.17 Cleaver Brooks 3 0.005 0.020 0.020 0.002 0.266 0.015 0.224 0.005 1.17 Heavy Duty Machining Operation HDM-01 0 0 0 0 0 1.66 0 0 0 HDM-02 0 0 0 0 0 1.66 0 0 0 Total PTE Before Controls of the New Emission Units:

6.72 3.95 3.95 3.36 265.10 11.02 56.37 3.41 4.66

1PM2.5 listed is direct PM2.5. 2Single highest HAP. Formaldehyde


PTE Increase of the Modified Emission Unit(s)/Process(es) (ton/year)

Process / Emission Unit PM PM10 PM2.51 SO2 NOX VOC CO Single

HAP2 Total HAPs

PTE Before Modification (Containerized Test Cell EU-22-LDD6)

2.15 1.23 1.23 1.07 44.92 1.84 17.63 0.002 0.03

PTE After Modification (Containerized Test Cell EU-22-LDD6)

4.77 4.60 4.60 3.86 187.76 139.35 45.53 4.74 15.66

Total PTE Increase of the Modified Emission Unit(s)/Process

2.62 3.37 3.37 2.79 142.85 137.51 27.90 4.74 15.63

1PM2.5 listed is direct PM2.5. 2Single highest HAP. Toluene Appendix A of this TSD reflects the detailed potential emissions of the modification.

PTE Increases Due to the Modification (ton/year)

PM PM10 PM2.51 SO2 NOX VOC CO Single HAP2

Total HAPs

Total PTE Before Controls of the New Emission Units

6.72 3.95 3.95 3.36 265.10 11.02 56.37 3.41 4.66

Total PTE Increase of the

Modified Emission

Unit(s)/Process

2.62 1.50 1.50 1.31 142.85 3.59 21.55 4.74 15.63

Total PTE of the Modification 9.35 5.45 5.45 4.67 407.95 14.61 77.92 4.74 20.29

1PM2.5 listed is direct PM2.5. 2Single highest HAP. Toluene Appendix A of this TSD reflects the detailed potential emissions of the modification. (a) Approval to Construct

Pursuant to 326 IAC 2-7-10.5(g)(4), a Significant Source Modification is required because this modification has the potential to emit NOx, VOC, and CO at greater than or equal to twenty-five (25) tons per year.

(b) Approval to Operate Pursuant to 326 IAC 2-7-12(d)(1), this change to the permit is being made through a Significant Permit Modification because this modification does not qualify as a Minor Permit Modification or as an Administrative Amendment.

PTE of the Entire Source After Issuance of the Part 70 Modification

The table below summarizes the after issuance source-wide potential to emit, reflecting all limits, of the emission units. Any control equipment is considered federally enforceable only after issuance of the Part 70 source and permit modification, and only to the extent that the effect of the control equipment is made

Cummins, Inc. Columbus Engine Plant (CEP) Page 7 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 practically enforceable in the permit. If the control equipment has been determined to be integral, the table reflects the potential to emit (PTE) after consideration of the integral control device.

Source-Wide Emissions After Issuance (ton/year)

PM1 PM101 PM2.51, 2 SO2 NOX VOC CO Single HAP3

Total HAP

s Total PTE of Entire Source Excluding Fugitives*

107.39 100.22 98.88 86.38 241.49(4) 173.94 239.54(4) 6.14 15.95

Title V Major Source Thresholds

NA 100 100 100 100 100 100 10 25

PSD Major Source Thresholds

250 250 250 250 250 250 250 -- --

1Under the Part 70 Permit program (40 CFR 70), PM10 and PM2.5, not particulate matter (PM), are each considered as a "regulated air pollutant.” 2PM2.5 listed is direct PM2.5. 3Single highest source-wide HAP Toluene 4 PSD minor limits to render 326 IAC 2-2 not applicable. *Fugitive HAP emissions are always included in the source-wide emissions.

The source opted to take limit(s) in order to render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable to this source. See Technical Support Document (TSD) State Rule Applicability - Entire Source section, 326 IAC 2-2 (PSD) for more information regarding the limit(s). (a) This existing minor PSD stationary source will continue to be minor under 326 IAC 2-2 because

the emissions of each PSD regulated pollutant will continue to be less than the PSD major source thresholds.

(b) This existing area source of HAP will continue to be an area source of HAP, as defined in 40 CFR

63.2, because HAP emissions will continue to be less than ten (10) tons per year for any single HAP and less than twenty-five (25) tons per year of a combination of HAPs. Therefore, this source is an area source under Section 112 of the Clean Air Act (CAA).

Federal Rule Applicability Determination

Due to the modification at this source, federal rule applicability has been reviewed as follows: New Source Performance Standards (NSPS): (a) The requirements of the New Source Performance Standard for Stationary Compression Ignition

Internal Combustion Engines, 40 CFR 60, Subpart IIII, are not included in this permit for the Electronic Engine Test Cells since the provisions of this subpart are not applicable to stationary CI ICE being used at a stationary CI ICE test cell/stand.

(b) The requirements of the NSPS for Small Industrial-Commercial-Institutional Steam Generating

Units, 40 CFR 60, Subpart Dc (40 CFR Part 60.40c - 60.48c) (326 IAC 12), are not included in the permit since each of the steam generating units at this source has a heat input rate less than or equal to 10 million Btu per hour (MMBtu/hr).

Cummins, Inc. Columbus Engine Plant (CEP) Page 8 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 (c) There are no New Source Performance Standards (40 CFR Part 60) and 326 IAC 12 included in

the permit for this proposed modification. National Emission Standards for Hazardous Air Pollutants (NESHAP): (a) The requirements of the National Emission Standards for Hazardous Air Pollutants (NESHAP) for

Stationary Reciprocating Internal Combustion Engines (326 IAC 20-82), 40 CFR 63, Subpart ZZZZ are not included in the permit for the Electronic Engine Test Cells since the provisions of this subpart are not applicable to stationary CI ICE being used at a stationary CI ICE test cell/stand.

(b) The requirements of the National Emission Standards for Hazardous Air Pollutant (NESHAP) for

Engine Test Cells/Stands, 40 CFR 63, Subpart PPPPP (326 IAC 20-75), are not included in the permit for the Electronic Engine Test Cells since the Electronic Engine Test Cells are not located at or are part of a major source of hazardous air pollutants (HAP) emissions, as defined in section 112(a) of the Clean Air Act (CAA).

(c) The requirements of the National Emission Standards for Hazardous Air Pollutant (NESHAP) for

Industrial, Commercial, and Institutional Boilers Area Sources, 40 CFR 63, Subpart JJJJJJ, are not included in the permit for the Natural Gas-fired Boilers. Pursuant to 40 CFR 6311195(e), this subpart exempts gas-fired boilers.

(d) The requirements of the National Emission Standards for Hazardous Air Pollutant (NESHAP) for

Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters, 40 CFR 63, Subpart DDDDD (326 IAC 20-95), are not included in the permit for Natural Gas-fired Boilers since the Natural Gas-fired Boilers are not located at or are part of a major source of hazardous air pollutants (HAP) emissions, as defined in section 112(a) of the Clean Air Act (CAA).

(e) There are no National Emission Standards for Hazardous Air Pollutants under 40 CFR 63, 326

IAC 14 and 326 IAC 20 included for this proposed modification. Compliance Assurance Monitoring (CAM): (a) Pursuant to 40 CFR 64.2, Compliance Assurance Monitoring (CAM) is applicable to each

pollutant-specific emission unit that meets the following criteria: (1) has a potential to emit before controls equal to or greater than the major source threshold

for the regulated pollutant involved; (2) is subject to an emission limitation or standard for that pollutant (or a surrogate thereof);

and (3) uses a control device, as defined in 40 CFR 64.1, to comply with that emission limitation

or standard.

(b) Pursuant to 40 CFR 64.2(b)(1)(i), emission limitations or standards proposed after November 15, 1990 pursuant to a NSPS or NESHAP under Section 111 or 112 of the Clean Air Act are exempt from the requirements of CAM. Therefore, an evaluation was not conducted for any emission limitations or standards proposed after November 15, 1990 pursuant to a NSPS or NESHAP under Section 111 or 112 of the Clean Air Act.

Based on this evaluation, the requirements of 40 CFR Part 64, CAM, are not applicable to any of the new or modified units as part of this modification since none of the new or modified emission units have a potential to emit before controls equal to or greater than the major source threshold, is subject to an emisison limitation or standard, or uses a control device to comply with any emission limitation or standard.


State Rule Applicability - Entire Source

Due to this modification, state rule applicability has been reviewed as follows: 326 IAC 2-2 (PSD) PSD applicability is discussed under the Permit Level Determination – PSD section and the Permit Level Determination - PSD Emissions Increase section of this document. PSD Minor Source Limits In order to render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable, the Permittee shall comply with the following:

(a) The total NOx Emissions from the following twenty-four (24) Test Cells shall not exceed 182 tons

per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3 EU-05 LDTC5 EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4 EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

This is an existing NOx PSD minor limit and is being revised to include the 2 new test cells and also to reflect the modification to EU-22 LDD6. (b) The total CO emissions from the following twenty-four (24) Test Cells shall not exceed 195 tons

per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3 EU-05 LDTC5 EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4


Emission Unit ID EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

The addition of the 2 new test cells and the modification of the Containerized Test Cell (EU-22 LDD6) increases the unlimited CO PTE to be greater than 250 tons per year. A new CO PSD minor limit is being added such that 326 IAC 2-2 PSD does not apply.

Compliance with these limits, combined with the potential to emit NOx, VOC, and CO from all other emission units at this source, shall limit the source-wide total potential to emit of NOx, VOC, and CO to less than two hundred and fifty (250) tons per twelve (12) consecutive month period, each, and shall render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable. 326 IAC 2-4.1 (Major Sources of Hazardous Air Pollutants (HAP)) The provisions of 326 IAC 2-4.1 apply to any owner or operator who constructs or reconstructs a major source of hazardous air pollutants (HAP), as defined in 40 CFR 63.41, after July 27, 1997, unless the major source has been specifically regulated under or exempted from regulation under a NESHAP that was issued pursuant to Section 112(d), 112(h), or 112(j) of the Clean Air Act (CAA) and incorporated under 40 CFR 63. On and after June 29, 1998, 326 IAC 2-4.1 is intended to implement the requirements of Section 112(g)(2)(B) of the Clean Air Act (CAA). The operation of this source will emit less than ten (10) tons per year for a single HAP and less than twenty-five (25) tons per year for a combination of HAPs. Therefore, 326 IAC 2-4.1 does not apply. 326 IAC 2-6 (Emission Reporting) Since this source is required to have an operating permit under 326 IAC 2-7, Part 70 Permit Program, this source is subject to 326 IAC 2-6 (Emission Reporting). In accordance with the compliance schedule in 326 IAC 2-6-3, an emission statement must be submitted triennially. The emission statement shall contain, at a minimum, the information specified in 326 IAC 2-6-4. 326 IAC 2-7-6(5) (Annual Compliance Certification) The U.S. EPA Federal Register 79 FR 54978 notice does not exempt Title V Permittees from the requirements of 40 CFR 70.6(c)(5)(iv) or 326 IAC 2-7-6(5)(D), but the submittal of the Title V annual compliance certification to IDEM satisfies the requirement to submit the Title V annual compliance certifications to EPA. IDEM does not intend to revise any permits since the requirements of 40 CFR 70.6(c)(5)(iv) or 326 IAC 2-7-6(5)(D) still apply, but Permittees can note on their Title V annual compliance certifications that submission to IDEM has satisfied reporting to EPA per Federal Register 79 FR 54978. This only applies to Title V Permittees and Title V compliance certifications. 326 IAC 5-1 (Opacity Limitations) This source is subject to the opacity limitations specified in 326 IAC 5-1-2(1). 326 IAC 6-4 (Fugitive Dust Emissions Limitations) Pursuant to 326 IAC 6-4 (Fugitive Dust Emissions Limitations), the source shall not allow fugitive dust to escape beyond the property line or boundaries of the property, right-of-way, or easement on which the source is located, in a manner that would violate 326 IAC 6-4. 326 IAC 6-5 (Fugitive Particulate Matter Emission Limitations) This source is not subject to the requirements of 326 IAC 6-5, because the source has potential fugitive particulate emissions of less than twenty-five (25) tons per year.

Cummins, Inc. Columbus Engine Plant (CEP) Page 11 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 326 IAC 6.5 (Particulate Matter Limitations Except Lake County) Pursuant to 326 IAC 6.5-1-1(a), this source (located in Bartholomew County) is not subject to the requirements of 326 IAC 6.5 because it is not located in one of the following counties: Clark, Dearborn, Dubois, Howard, Marion, St. Joseph, Vanderburgh, Vigo or Wayne. 326 IAC 6.8 (Particulate Matter Limitations for Lake County) Pursuant to 326 IAC 6.8-1-1(a), this source (located in Bartholomew County) is not subject to the requirements of 326 IAC 6.8 because it is not located in Lake County. 326 IAC 9-1 (Carbon Monoxide Emission Requirements) The requirements of 326 IAC 9-1 do not apply to the source because this source does not operate a catalyst regeneration petroleum cracking system or a petroleum fluid coker, grey iron cupola, blast furnace, basic oxygen steel furnace, or other ferrous metal smelting equipment.

State Rule Applicability – Individual Facilities

Due to this modification, state rule applicability has been reviewed as follows: Electronic Engine Test Cells (EU-23 EMC1 and EU-24 EMC2) 326 IAC 6-2-2 (Particulate Matter Emission Limitations for Sources of Indirect Heating) The Electronic Engine Test Cells (EU-23 EMC1 and EU-24 EMC2) are not a source of indirect heating, as defined in 326 IAC 1-2-19 “Combustion for indirect heating”. Therefore, the requirements of 326 IAC 6-2 do not apply. 326 IAC 6-3-2 (Particulate Matter Limitations for Manufacturing Processes) Pursuant to 326 IAC 6-3-1.5(2), the Electronic Engine Test Cells (EU-23 EMC1 and EU 24-EMC2) are not subject to the provisions of 326 IAC 6-3 because each is not considered a manufacturing process as defined in 326 IAC 6-3-1.5(2). 326 IAC 7-1.1 (Sulfur Dioxide Emission Limitations) The uncontrolled sulfur dioxide (SO2) emissions from the Electronic Engine Test Cells (EU-23 EMC1 and EU-24 EMC2) are less than twenty-five (25) tons per year and ten (10) pounds per hour; therefore, the Electronic Engine Test Cells (EU-23-EMC1 and EU-24-EMC2) are not subject to the requirements of 326 IAC 7-1.1. 326 IAC 8-1-6 (VOC Rules: General Reduction Requirements for New Facilities) Even though the Electronic Engine Test Cells (EU-23 EMC1 and EU-24 EMC2) were constructed after January 1, 1980, each test cell is not subject to the requirements of 326 IAC 8-1-6 because its unlimited VOC potential emissions are less than twenty-five (25) tons per year. 326 IAC 2-4.1 (Major Sources of Hazardous Air Pollutants (HAP)) The two (2) Electronic Engine Test Cells (EU-23 EMC1 and EU-24 EMC2) have HAP emissions less than ten (10) tons per year for a single HAP and twenty-five (25) tons per year for any combination of HAPs; therefore, 326 IAC 2-4.1 is not applicable to these facilities. Natural Gas-fired Boilers 326 IAC 6-2-4 (Particulate Matter Emission Limitations for Sources of Indirect Heating) Each of the eight (8) new natural gas-fired boilers is subject to the requirements of 326 IAC 6-2-4, since they each are a source of indirect heating. Pursuant to 326 IAC 6-2-1(d), indirect heating facilities which received permit to construct after September 21, 1983 are subject to the requirements of 326 IAC 6-2-4. The particulate matter emissions (Pt) shall be limited by the following equation:

𝑃𝑃𝑃𝑃 = 1.09𝑄𝑄0.26


Where: Pt = Pounds of particulate matter emitted per million British thermal units (lb/MMBtu).

Q = Total source maximum operating capacity rating in MMBtu/hr heat input. The maximum operating capacity rating is defined as the maximum capacity at which the facility is operated or the nameplate capacity, whichever is specified in the facility’s permit application, except when some lower capacity is contained in the facility’s operation permit; in which case, the capacity specified in the operation.

Pursuant to 326 IAC 6-2-4 (Particulate Emission Limitations for Sources of Indirect Heating), the particulate emissions from the following units shall be less than the particulate emissions limitation (Pt) in pounds per MMBtu heat input, as follows:

Indirect Heating Units Which Began Operation After September 21, 1983

Facility Construction Date

Operating Capacity

(MMBtu/hr)

Q (MMBtu/hr)

Calculated Pt

(lb/MMBtu)

Particulate Limitation,

(Pt) (lb/MMBtu)

PM PTE based on

AP-42 (lb/MMBtu)

Raypak-61 Boiler 1 1997 1.5

8.34 0.63 0.60

0.0019 Raypak-61 Boiler 2 1997 1.5 0.0019 Raypak-61 Boiler 3 1997 1.5 0.0019 Aerco 96 Boiler 1 1997 0.96 0.0019 Aerco 96 Boiler 2 1997 0.96 0.0019 Aerco 96 Boiler 3 1997 0.96 0.0019 Aerco 96 Boiler 4 1997 0.96 0.0019 Raypak-72 Boiler 1 2008 1.26 10.86 0.59 0.59 0.0019 Raypak-72 Boiler 2 2008 1.26 0.0019 Lochinvar 1 2009 2.075

23.36 0.48 0.48

0.0019 Lochinvar 2 2009 2.075 0.0019 Lochinvar 3 2009 2.075 0.0019 Lochinvar 4 2009 2.075 0.0019 B1 2009 2.1 0.0019 B2 2009 2.1 0.0019 Raypak-72 Boiler 3 2010 1.26 24.62 0.47 0.47 0.0019 Cleaver Brooks 1 2019 0.62

28.48 0.46

0.46 0.0019 Cleaver Brooks 2 2019 0.62 0.46 0.0019 Cleaver Brooks 3 2019 0.62 0.46 0.0019 Lochinvar 5 2019 0.40 0.46 0.0019 Lochinvar 6 2019 0.40 0.46 0.0019 Lochinvar 7 2019 0.40 0.46 0.0019 Lochinvar 8 2019 0.40 0.46 0.0019 Lochinvar 9 2019 0.40 0.46 0.0019 Where: Q = Includes the capacity (MMBtu/hr) of the new units and the capacities for those units which were

in operation at the source at the time the new units was constructed. The boilers each have PM emissions of 0.0019 lb/MMBtu; therefore, they are in compliance with 326 IAC 6-2-4 without the use of a control device. Heavy Duty Machining Operations (HDM-01 and HDM-02) 326 IAC 6-3-2 (Particulate Matter Limitations for Manufacturing Processes) Pursuant to 326 IAC 6-3-1(b)(14), manufacturing processes with potential emissions less than five hundred fifty-one thousandths (0.551) pound per hour are exempt from 326 IAC 6-3; therefore, the Heavy Duty Machining Operations (HDM-01 and HDM-02) are exempt from the requirements of this rule.

Cummins, Inc. Columbus Engine Plant (CEP) Page 13 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 326 IAC 8-1-6 (VOC Rules: General Reduction Requirements for New Facilities) Even though the Heavy Duty Machining Operations (HDM-01 and HDM-02) were constructed after January 1, 1980, each machining operation is not subject to the requirements of 326 IAC 8-1-6 because its unlimited VOC potential emissions are less than twenty-five (25) tons per year. Containerized Test Cell (EU-22 LDD6) 326 IAC 6-2-2 (Particulate Matter Emission Limitations for Sources of Indirect Heating) The Containerized Test Cell (EU-22 LDD6) is not a source of indirect heating, as defined in 326 IAC 1-2-19 “Combustion for indirect heating”. Therefore, the requirements of 326 IAC 6-2 do not apply. 326 IAC 6-3-2 (Particulate Matter Limitations for Manufacturing Processes) Pursuant to 326 IAC 6-3-1.5(2), the Containerized Test Cell (EU-22 LDD6) is not subject to the provisions of 326 IAC 6-3 because it is not considered a manufacturing process as defined in 326 IAC 6-3-1.5(2). 326 IAC 7-1.1 (Sulfur Dioxide Emission Limitations) The uncontrolled sulfur dioxide (SO2) emissions from the Containerized Test Cell (EU-22 LDD6) are less than twenty-five (25) tons per year and ten (10) pounds per hour; therefore, the Emergency Generator is not subject to the requirements of 326 IAC 7-1.1. 326 IAC 8-1-6 (VOC Rules: General Reduction Requirements for New Facilities) Even though the Containerized Test Cell (EU-22 LDD6) was constructed after January 1, 1980, the test cell is not subject to the requirements of 326 IAC 8-1-6 because its unlimited VOC potential emissions are less than twenty-five (25) tons per year. 326 IAC 2-4.1 (Major Sources of Hazardous Air Pollutants (HAP)) The Containerized Test Cell (EU-22 LDD6) has HAP emissions less than ten (10) tons per year for a single HAP and twenty-five (25) tons per year for any combination of HAPs; therefore, 326 IAC 2-4.1 is not applicable to this facility.

Compliance Determination and Monitoring Requirements

Permits issued under 326 IAC 2-7 are required to assure that sources can demonstrate compliance with all applicable state and federal rules on a continuous basis. All state and federal rules contain compliance provisions; however, these provisions do not always fulfill the requirement for a continuous demonstration. When this occurs, IDEM, OAQ, in conjunction with the source, must develop specific conditions to satisfy 326 IAC 2-7-5. As a result, Compliance Determination Requirements are included in the permit. The Compliance Determination Requirements in Section D of the permit are those conditions that are found directly within state and federal rules and the violation of which serves as grounds for enforcement action. If the Compliance Determination Requirements are not sufficient to demonstrate continuous compliance, they will be supplemented with Compliance Monitoring Requirements, also in Section D of the permit. Unlike Compliance Determination Requirements, failure to meet Compliance Monitoring conditions would serve as a trigger for corrective actions and not grounds for enforcement action. However, a violation in relation to a compliance monitoring condition will arise through a source’s failure to take the appropriate corrective actions within a specific time period. The compliance determination requirements applicable to this source due to this modification are as follows: (a) In order to determine compliance with the PSD Minor Limit, the NOx emissions from the twenty-

four (24) Test Cells shall be calculated using the following equation:

𝑁𝑁𝑁𝑁𝑁𝑁 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 (𝑃𝑃𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑃𝑃ℎ

) = �(𝐷𝐷 𝑁𝑁 𝐸𝐸𝐸𝐸𝐷𝐷) + (𝐵𝐵 𝑁𝑁 𝐸𝐸𝐸𝐸𝐵𝐵) + (𝐽𝐽 𝑁𝑁 𝐸𝐸𝐸𝐸𝐽𝐽) + (𝑁𝑁 𝑁𝑁 𝐸𝐸𝐸𝐸𝑁𝑁) + (𝐺𝐺 𝑁𝑁 𝐸𝐸𝐸𝐸𝐺𝐺)

2000 𝑙𝑙𝑙𝑙𝐸𝐸𝑃𝑃𝐸𝐸𝐸𝐸

Cummins, Inc. Columbus Engine Plant (CEP) Page 14 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 Where:

D = Diesel Fuel Usage (gal/month) EFD = NOx emission factor for diesel fuel combustion = 0.297 (lb/gal) B = Biodiesel Fuel Usage (gal/month) EFB = NOx emission factor for biodiesel fuel combustion = 0.273 (lb/gal) J = JP-8 Fuel Usage (gal/month) EFJ = NOx emission factor for JP-8 fuel combustion = 0.293 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = NOx emission factor for natural gas combustion = (4161.60 lb/MMSCF) G = Gasoline Usage (gal/month) EFG = NOx emission factor for gasoline combustion = 0.212 (lb/gal)

(b) In order to determine compliance with the PSD Minor Limit, the CO emissions from the twenty-four (24) Test Cells shall be calculated using the following equation:

𝐶𝐶𝑁𝑁 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 ( 𝑡𝑡𝑡𝑡𝑡𝑡𝑡𝑡

𝑚𝑚𝑡𝑡𝑡𝑡𝑡𝑡ℎ) = ∑ (𝐷𝐷 𝑥𝑥 𝐸𝐸𝐸𝐸𝐷𝐷)+(𝐵𝐵 𝑥𝑥 𝐸𝐸𝐸𝐸𝐵𝐵)+(𝐽𝐽 𝑥𝑥 𝐸𝐸𝐸𝐸𝐽𝐽)+(𝑁𝑁 𝑥𝑥 𝐸𝐸𝐸𝐸𝑁𝑁)+ (𝐺𝐺 𝑥𝑥 𝐸𝐸𝐸𝐸𝐺𝐺)


∑ (𝐷𝐷1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐷𝐷1)+(𝐵𝐵1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐵𝐵1)+(𝐽𝐽1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐽𝐽1)+(𝑁𝑁1 𝑁𝑁 𝐸𝐸𝐸𝐸𝑁𝑁1)+ (𝐺𝐺1 𝑁𝑁 𝐸𝐸𝐸𝐸𝐺𝐺1)

2000𝑙𝑙𝑙𝑙𝐸𝐸𝑃𝑃𝐸𝐸𝐸𝐸


D = Diesel Fuel Usage (gal/month) EFD = CO emission factor for diesel fuel combustion = 0.116 (lb/gal) B = Biodiesel Fuel Usage (gal/month) EFB = CO emission factor for biodiesel fuel combustion = 0.107 (lb/gal) J = JP-8 Fuel Usage (gal/month) EFJ = CO emission factor for JP-8 fuel combustion = 0.115 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = CO emission factor for natural gas combustion = (323.34 lb/MMSCF) G = Gasoline Usage (gal/month) EFG = CO emission factor for gasoline combustion = 0.129 (lb/gal)


D1 = Diesel Fuel Usage (gal/month) EFD1 = CO emission factor for diesel fuel combustion = 0.130 (lb/gal) B1 = Biodiesel Fuel Usage (gal/month) EFB1 = CO emission factor for biodiesel fuel combustion = 0.120 (lb/gal) J1 = JP-8 Fuel Usage (gal/month) EFJ1 = CO emission factor for JP-8 fuel combustion = 0.128 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = CO emission factor for natural gas combustion = (323.34 lb/MMSCF) G1 = Gasoline Usage (gal/month) EFG1 = CO emission factor for gasoline combustion = 0.129 (lb/gal)

These monitoring conditions are necessary in order to assure compliance with 326 IAC 2-2.

Proposed Changes

As part of this permit approval, the permit may contain new or different permit conditions and some conditions from previously issued permits/approvals may have been corrected, changed, or removed. These corrections, changes, and removals may include Title I changes.

Cummins, Inc. Columbus Engine Plant (CEP) Page 15 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 The following changes listed below are due to the proposed modification. Deleted language appears as strikethrough text and new language appears as bold text (these changes may include Title I changes): ...

A.2 Emission Units and Pollution Control Equipment Summary

[326 IAC 2-7-4(c)(3)][326 IAC 2-7-5(14)] This stationary source consists of the following emission units and pollution control devices:

... (b) Seven (7) Cycle Test Cells, consisting of the following:

Emission Unit ID


Maximum Capacity

Fuel Type


EU-01 LDTC1

1974 or prior

25.46 MMBtu/hr 500 HP

(combined) Diesel,

Biodiesel, or JP-8

none

Stack 1


... (d) Four (4) Cold Test Cells, consisting of the following:

Emission Unit ID


Type Control Device

(ID) Stack ID

EU-13

2008

1.00 MMBtu/hr 142.86 HP


none

Stack 13

EU-14 1.00 MMBtu/hr 142.86

HP Stack 14

EU-15 1.00 MMBtu/hr 142.86

HP Stack 15

EU-16 1.00 MMBtu/hr 142.86

HP Stack 16

... (f) One (1) Containerized Test Cell, identified as EU-22 LDD6, capable of testing with

diesel, biodiesel, JP-8, natural gas, or gasoline, constructed in 2018 and approved in 20198 for constructionmodification, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22.


Emission Unit ID



Control Device

(ID) Stack ID


construction


none Stack 23


Cummins, Inc. Columbus Engine Plant (CEP) Page 16 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 A.3 Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] This stationary source also includes the following insignificant activities which are specifically regulated, as defined in 326 IAC 2-7-1(21): ... (a) Sixteen (16) Natural Gas-fired Boilers, consisting of the following:


Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack

ID

... Boiler Lochinvar 5 2019* 0.400 none L5 Boiler Lochinvar 6 2019* 0.400 none L6 Boiler Lochinvar 7 2019* 0.400 none L7 Boiler Lochinvar 8 2019* 0.400 none L8 Boiler Lochinvar 9 2019* 0.400 none L9 Boiler Cleaver

Brooks 1 2019* 0.620 none CB1



* approved in 2019 for construction

... A.4 Non-Specifically Regulated Insignificant Activities

[326 IAC 2-7-1(21)][326 IAC 2-7-4(c)][326 IAC 2-7-5(14)] This stationary source also includes the following insignificant activities which are not specifically regulated, as defined in 326 IAC 2-7-1(21):

... (p) Two (2) Heavy Duty Machining Operations, identified as HDM-01 and HDM-02,

approved in 2019 for construction, with a maximum machining solution usage of 500 gallons per year each, using mist collectors for particulate control, and exhausting indoors.

... B.9 Annual Compliance Certification [326 IAC 2-7-6(5)]

(a) The Permittee shall annually submit a compliance certification report which addresses the status of the source’s compliance with the terms and conditions contained in this permit, including emission limitations, standards, or work practices. All certifications shall cover the time period from January 1 to December 31 of the previous year, and shall be submitted no later than July 1 of each year to: Indiana Department of Environmental Management Compliance and Enforcement Branch, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 and


United States Environmental Protection Agency, Region V5 Air and Radiation Division, Air Enforcement Branch - Indiana (AE-17J) 77 West Jackson Boulevard Chicago, Illinois 60604-3590

... B.19 Operational Flexibility [326 IAC 2-7-20][326 IAC 2-7-10.5]

(a) The Permittee may make any change or changes at the source that are described in 326 IAC 2-7-20(b) or (c) without a prior permit revision, if each of the following conditions is met: ... (4) The Permittee notifies the:

Indiana Department of Environmental Management Permit Administration and Support Section, Office of Air Quality 100 North Senate Avenue MC 61-53 IGCN 1003 Indianapolis, Indiana 46204-2251 and United States Environmental Protection Agency, Region V5 Air and Radiation Division, Regulation Development Branch - Indiana (AR-18J) 77 West Jackson Boulevard Chicago, Illinois 60604-3590

in advance of the change by written notification at least ten (10) days in advance of the proposed change. The Permittee shall attach every such notice to the Permittee's copy of this permit; and

... SECTION D.1 EMISSIONS UNIT OPERATION CONDITIONS

Emissions Unit Description: (a) One (1) Fuel Test Cell, identified as EU-04 LDTC4, constructed in 2008, with a maximum



Emission Unit ID


Maximum Capacity

Fuel Type


EU-01 LDTC1

1974 or prior

25.46 HP (combined)500

HP Diesel,

Biodiesel, or JP-8

none

Stack 1



...


Emission Unit ID


Type Control Device

(ID) Stack ID

EU-13

2008

1.00 MMBtu/hr 142.86 HP


none

Stack 13

EU-14 1.00 MMBtu/hr 142.86

HP Stack 14

EU-15 1.00 MMBtu/hr 142.86

HP Stack 15

EU-16 1.00 MMBtu/hr 142.86

HP Stack 16

... (f) One (1) Containerized Test Cell, identified as EU-22 LDD6, capable of testing with diesel,

biodiesel, JP-8, natural gas, or gasoline, constructed in 2018 and approved in 20198 for constructionmodification, with a maximum capacity of 675 HP, using no controls, and exhausting to Stack 22.


Emission Unit ID


Type Control Device

(ID) Stack ID

EU-23 EMC1 Approved in

2019 for construction

605 HP Diesel, Biodiesel, JP-8,

or Natural

gas

none

Stack 23


(The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

Emission Limitations and Standards [326 IAC 2-7-5(1)] D.1.1 Prevention of Significant Deterioration (PSD) Minor Limits [326 IAC 2-2]

In order to render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable, the Permittee shall comply with the following: (a) The total NOx emissions from the following twenty-two four (242) Test Cells, identified as

EU-04 LDTC4, EU-01 LDTC1, EU-02 LDTC2, EU-03 LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, and EU-22 LDD6, shall not exceed 182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3


Emission Unit ID EU-05 LDTC5 EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4 EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-18 LDTC9 EU-19 LDTC10 EU-20 LDTC11 EU-21 LDTC12 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

(b) The total CO emissions from the following twenty-four (24) Test Cells shall not

exceed 195 tons per twelve (12) consecutive month period, with compliance determined at the end of each month:

Emission Unit

ID EU-04 LDTC4 EU-01 LDTC1 EU-02 LDTC2 EU-03 LDTC3 EU-05 LDTC5 EU-06 LDTC6 EU-07 LDTC7 EU-08 LDTC8 EU-09 LDD1 EU-10 LDD2 EU-11 LDD3 EU-12 LDD4 EU-17 LDD5 EU-13 EU-14 EU-15 EU-16 EU-18 LDTC9 EU-19 LDTC10 EU-20 LDTC11 EU-21 LDTC12 EU-22 LDD6 EU-23 EMC1 EU-24 EMC2

Compliance with this limit,these limits in combination with potential to emit NOx and CO emissions from all other emission units at this source, shall limit the source-wide potential to


emit NOx and CO emissions to less than 250 tons per year, each, and shall render the requirements of 326 IAC 2-2 (Prevention of Significant Deterioration (PSD)) not applicable. ...

Compliance Determination Requirements [326 IAC 2-7-5(1)][326 IAC 2-7-6(1)] D.1.3 Compliance Determination

(a) In order to determine compliance with the PSD Minor Limit in Condition D.1.1(a), the NOx emissions from the twenty-two four (224) Test Cells shall be calculated using the following equation:

𝑁𝑁𝑁𝑁𝑁𝑁 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 (𝑃𝑃𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑃𝑃ℎ

) = �(𝐷𝐷 𝑁𝑁 𝐸𝐸𝐸𝐸𝐷𝐷) + (𝐵𝐵 𝑁𝑁 𝐸𝐸𝐸𝐸𝐵𝐵) + (𝐽𝐽 𝑁𝑁 𝐸𝐸𝐸𝐸𝐽𝐽) + (𝑵𝑵 𝒙𝒙 𝑬𝑬𝑬𝑬𝑵𝑵) + (𝑮𝑮 𝒙𝒙 𝑬𝑬𝑬𝑬𝑮𝑮)

2000 𝑙𝑙𝑙𝑙𝐸𝐸𝑃𝑃𝐸𝐸𝐸𝐸

Where:

D = Diesel Fuel Usage (gal/month) EFD = NOx emission factor for diesel fuel combustion = 0.297 (lb/gal) B = Biodiesel Fuel Usage (gal/month) EFB = NOx emission factor for biodiesel fuel combustion = 0.273 (lb/gal) J = JP-8 Fuel Usage (gal/month) EFJ = NOx emission factor for JP-8 fuel combustion = 0.293 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = NOx emission factor for natural gas combustion = 4161.60 (lb/MMSCF) G = Gasoline Usage (gal/month) EFG = NOx emission factor for gasoline combustion = 0.212 (lb/gal)

(b) In order to determine compliance with the PSD Minor Limit in Condition D.1.1(b), the CO emissions from the twenty-four (24) Test Cells shall be calculated using the following equation:

𝑪𝑪𝑪𝑪 𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬𝑬 ( 𝒕𝒕𝑬𝑬𝑬𝑬𝑬𝑬

𝑬𝑬𝑬𝑬𝑬𝑬𝒕𝒕𝒎𝒎) = ∑ (𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑫𝑫)+(𝑩𝑩 𝒙𝒙 𝑬𝑬𝑬𝑬𝑩𝑩)+(𝑱𝑱 𝒙𝒙 𝑬𝑬𝑬𝑬𝑱𝑱)+(𝑵𝑵 𝒙𝒙 𝑬𝑬𝑬𝑬𝑵𝑵)+ (𝑮𝑮 𝒙𝒙 𝑬𝑬𝑬𝑬𝑮𝑮)

𝟐𝟐𝟐𝟐𝟐𝟐𝟐𝟐𝒍𝒍𝒍𝒍𝑬𝑬𝒕𝒕𝑬𝑬𝑬𝑬 +

∑ (𝑫𝑫𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑫𝑫𝑫𝑫)+(𝑩𝑩𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑩𝑩𝑫𝑫)+(𝑱𝑱𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑱𝑱𝑫𝑫)+(𝑵𝑵𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑵𝑵𝑫𝑫)+ (𝑮𝑮𝑫𝑫 𝒙𝒙 𝑬𝑬𝑬𝑬𝑮𝑮𝑫𝑫)

𝟐𝟐𝟐𝟐𝟐𝟐𝟐𝟐𝒍𝒍𝒍𝒍𝑬𝑬𝒕𝒕𝑬𝑬𝑬𝑬


D = Diesel Fuel Usage (gal/month) EFD = CO emission factor for diesel fuel combustion = 0.116 (lb/gal) B = Biodiesel Fuel Usage (gal/month) EFB = CO emission factor for biodiesel fuel combustion = 0.107 (lb/gal) J = JP-8 Fuel Usage (gal/month) EFJ = CO emission factor for JP-8 fuel combustion = 0.115 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = CO emission factor for natural gas combustion = (323.34 lb/MMSCF) G = Gasoline Usage (gal/month) EFG = CO emission factor for gasoline combustion = 0.129 (lb/gal)


D1 = Diesel Fuel Usage (gal/month) EFD1 = CO emission factor for diesel fuel combustion = 0.130 (lb/gal) B1 = Biodiesel Fuel Usage (gal/month) EFB1 = CO emission factor for biodiesel fuel combustion = 0.120 (lb/gal)


J1 = JP-8 Fuel Usage (gal/month) EFJ1 = CO emission factor for JP-8 fuel combustion = 0.128 (lb/gal) N = Natural Gas Usage (MMSCF/month) EFN = CO emission factor for natural gas combustion = (323.34 lb/MMSCF) G1 = Gasoline Usage (gal/month) EFG1 = CO emission factor for gasoline combustion = 0.129 (lb/gal)

Record Keeping and Reporting Requirements [326 IAC 2-7-5(3)] [326 IAC 2-7-19] D.1.4 Record Keeping Requirement

(a) To document the compliance status with Condition D.1.1, the Permittee shall maintain records in accordance with (1) and (48) below. Records maintained for (1) and (48) shall be taken monthly and shall be complete and sufficient to establish compliance with the NOx PSD Minor Limitemission limit established in Condition D.1.1.

(1) The amount of Diesel Fuel used in each of the all twenty-two four (224) Test

Cells, combined (in gallons) each month. (2) The amount of Biodiesel Fuel used in each of the all twenty-two four (224) Test

Cells, combined (in gallons) each month. (3) The amount of JP-8 Fuel used in each of the all twenty-two four (224) Test

Cells, combined (in gallons) each month. (4) The amount of Natural Gas used in each of the Test Cells, identified as EU-

22 LDD6, EU-23 EMC1, and EU-24 EMC2 (in MMSCF) each month. (5) The amount of Gasoline Fuel used in each of the Test Cells, identified as

EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2 (in gallons) each month. (6) The total NOx emissions each month and each compliance period

calculated using the equation in Condition D.1.4(a). (7) The total CO emissions each month and each compliance period calculated

using the equation in Condition D.1.4(b).

... D.1.56 Reporting Requirements

A quarterly summary of the information to document the compliance status with Conditions D.1.1(a) and D1.1(b), shall be submitted using the reporting forms located at the end of this permit, or its equivalent, not later than thirty (30) days following the end of each calendar quarter. The report submitted by the Permittee does require a certification that meets the requirements of 326 IAC 2-7-6(1) by a “responsible official” as defined by 326 IAC 2-7-1 (35). Section C - General Reporting Requirements contains the Permittee's obligations with regard to the reporting required by this condition.

... SECTION D.2 EMISSIONS UNIT OPERATION CONDITIONS

Emissions Unit Description: Specifically Regulated Insignificant Activities (b) Sixteen (16) Natural Gas-fired Boilers, consisting of the following:



Emission Unit ID


Maximum Input

Capacity (MMBtu/hr)

Control Device

(ID) Stack ID

...

Boiler Lochinvar 5 2019* 0.400 none L5 Boiler Lochinvar 6 2019* 0.400 none L6 Boiler Lochinvar 7 2019* 0.400 none L7 Boiler Lochinvar 8 2019* 0.400 none L8 Boiler Lochinvar 9 2019* 0.400 none L9 Boiler Cleaver

Brooks 1 2019* 0.620 none CB1



* approved in 2019 for construction (The information describing the process contained in this emissions unit description box is descriptive information and does not constitute enforceable conditions.)

Emission Limitations and Standards [326 IAC 2-7-5(1)] D.2.1 Particulate Emissions [326 IAC 6-2-4]

Pursuant to 326 IAC 6-2-4 (Particulate Emission Limitations for Sources of Indirect Heating), the particulate emissions from each of the following units shall be less than the particulate emissions limitation (Pt) in pounds per MMBtu heat input, as follows:

Emission Unit Unit ID Particulate Emissions

Limitation (Pt) (lb/MMBtu) ...

Boiler Cleaver Brooks 1

0.46

Boiler Cleaver Brooks 2 Boiler Cleaver Brooks 3 Boiler Lochinvar 5 Boiler Lochinvar 6 Boiler Lochinvar 7 Boiler Lochinvar 8 Boiler Lochinvar 9

...



Part 70 Quarterly Report Source Name: Cummins (Columbus Engine Plant)

Cummins, Inc. Columbus Engine Plant (CEP) Page 23 of 24 Columbus, Indiana TSD for SSM No. 005-41279-00015 Permit Reviewer: Sommer Cochran TSD for SPM No. 005-41384-00015 Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 Facility: Twenty-two four (242) Test Cells, identified as EU-04 LDTC4, EU-01 LDTC1,

EU-03 LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, and EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2

Parameter: NOx Emissions Limit: The total NOx emissions from the above mentioned twenty-two four (2224)

Test Cells, identified as EU-04 LDTC4, EU-01 LDTC1, EU-02 LDTC2, EU-03 LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, and EU-22 LDD6, shall not exceed 182 tons per twelve (12) consecutive month period, with compliance determined at the end of each month.

...

INDIANA DEPARTMENT OF ENVIRONMENTAL MANAGEMENT OFFICE OF AIR QUALITY

COMPLIANCE AND ENFORCEMENT BRANCH

Part 70 Quarterly Report Source Name: Cummins (Columbus Engine Plant) Source Address: 1000 5th Street, Columbus, Indiana 47201 Part 70 Permit No.: T005-39514-00015 Facility: Twenty-four (24) Test Cells, identified as EU-04 LDTC4, EU-01 LDTC1, EU-

03 LDTC3, EU-05 LDTC5, EU-06 LDTC6, EU-07 LDTC7, EU-08 LDTC8, EU-09 LDD1,EU-10 LDD2, EU-11 LDD3, EU-12 LDD4, EU-17 LDD5, EU-13, EU-14, EU-15, EU-16, EU-18 LDTC9, EU-19 LDTC10, EU-20 LDTC11, EU-21 LDTC12, EU-22 LDD6, EU-23 EMC1, and EU-24 EMC2

Parameter: CO Emissions Limit: The total CO emissions from the above mentioned twenty-four (24) Test

Cells, shall not exceed 195 tons per twelve (12) consecutive month period, with compliance determined at the end of each month.

QUARTER : YEAR:

Month

CO Emissions (tons)

CO Emissions (tons)

CO Emissions (tons)

This Month Previous 11 Months 12 Month Total





...

Conclusion and Recommendation

Unless otherwise stated, information used in this review was derived from the application and additional information submitted by the applicant. An application for the purposes of this review was received on March 29, 2019. The construction of this proposed modification shall be subject to the conditions of the attached proposed Part 70 Significant Source Modification No. 005-41279-00015. The operation of this proposed modification shall be subject to the conditions of the attached proposed Significant Permit Modification No. 005-41384-00015. The staff recommends to the Commissioner that the Part 70 Significant Source Modification and Significant Permit Modification be approved.

IDEM Contact

(a) If you have any questions regarding this permit, please contact Sommer Cochran, Indiana Department Environmental Management, Office of Air Quality, Permits Branch, 100 North Senate Avenue, MC 61-53 IGCN 1003, Indianapolis, Indiana 46204-2251, or by telephone at (317) 234-5376 or (800) 451-6027, and ask for Sommer Cochran or (317) 234-5376.

(b) A copy of the findings is available on the Internet at: http://www.in.gov/ai/appfiles/idem-caats/ (c) For additional information about air permits and how the public and interested parties can

participate, refer to the IDEM Air Permits page on the Internet at: http://www.in.gov/idem/airquality/2356.htm; and the Citizens' Guide to IDEM on the Internet at: http://www.in.gov/idem/6900.htm.





Source Summary

Page 1 of 12 TSD App A



Permit No.: T005-39514-00015



Permit Writer: Sommer Cochran

Unlimited Potential to Emit (tons/yr)PM PM10 PM2.5 SO2 NOx VOC CO Total HAPs Single Worst HAP

Test Cells 92.98 90.04 90.04 85.71 806.63 164.92 289 21.34 4.88 Toluene

Boilers 0.23 0.93 0.93 0.07 12.20 0.67 10.25 0.23 0.22 Hexane



Degreasers 0 0 0 0 0 0.60 0 0 0

Trimmers <1 <1 <1 0 0 0 0 0 0

Battery Assembly <1 <1 <1 0 0 <1 0 0 0

Grinding and Machining <1 <1 <1 0 0 3.31 0 0 0

VOC and HAP Storage Containers 0 0 0 0 0 1.01 0 <1 <1 Xylene

Cooling Towers 0.17 0.17 0.17 0 0 0 0 0 0

Welding 1.01 1.01 1.01 0 0 0 0 0.09 0.09 Mn

Paved Roads 8.83 1.77 0.43 0 0 0 0 0 0

Total 107.39 100.22 98.88 86.38 866.13 173.94 333.36 24.12 4.88 Toluene

Limited Emissions (tons/yr)PM PM10 PM2.5 SO2 NOx VOC CO Total HAPs Single Worst HAP

Test Cells 92.98 90.04 90.04 85.71 182 165 195 21.34 4.88 Toluene


Boilers 0.73 2.93 2.93 0.23 38.49 2.12 32.33 0.73 0.69 Hexane


Degreasers 0 0 0 0 0 0.60 0 0 0

Trimmers <1 <1 <1 0 0 0 0 0 0

Battery Assembly <1 <1 <1 0 0 <1 0 0 0

Grinding and Machining <1 <1 <1 0 0 3 0 0 0

VOC and HAP Storage Containers 0 0 0 0 0 1.01 0 <1 <1 Xylene

Cooling Towers 0.17 0.17 0.17 0 0 0 0 0 0

Welding 1.01 1.01 1.01 0 0 0 0 0.09 0.09 Mn

Paved Roads 8.83 1.77 0.43 0 0 0 0 0 0

Total 107.39 100.22 98.88 86.38 241.49 173.94 239.54 24.12 4.88 Toluene


Summary of Modification




Permit No.: T005-39514-00015




PTE Before Control of the New Emission Units (tons/yr)


Electronic Engine Test Cells EU-23-EMC1 1.92 1.10 1.10 0.96 75.68 2.19 15.80 0.979 Formaldehyde 1.33


Boilers Lochinvar 5 0.003 0.013 0.013 0.001 0.172 0.009 0.144 0.003 Hexane 0.003








Heavy Duty Machining Operation HDM-01 0 0 0 0 0 1.66 0 0.00 0.00

HDM-02 0 0 0 0 0 1.66 0 0.00 0.00

Total PTE of the New Units 6.72 3.95 3.95 3.36 265.10 11.02 56.37 3.41 Formaldehyde 4.66

PTE Before Control of the Modified Emission Units (tons/yr)


Containerized Test Cell EU-22 LDD6

PTE Before Modification 2.15 1.23 1.23 1.07 44.92 1.84 17.63 0.002 Formaldehyde 0.03

PTE After Modification 4.77 2.73 2.73 2.38 187.76 5.43 39.18 4.74 Toluene 15.66

PTE Increase for the Modification 2.62 1.50 1.50 1.31 142.85 3.59 21.55 4.74 Toluene 15.63

PTE Increase Due to the Modification (tons/yr)

PM PM10 PM2.5 SO2 NOx VOC CO Single Worst HAP Total HAPs

Total PTE Before Control of the New Emission Units 6.72 3.95 3.95 3.36 265.10 11.02 56.37 3.41 Formaldehyde 4.66

Total PTE Before Control of the Modified Emission Units 2.62 1.50 1.50 1.31 142.85 3.59 21.55 4.74 Toluene 15.63

Total PTE of the Modification 9.35 5.45 5.45 4.67 407.95 14.61 77.92 4.74 Toluene 20.29


HAPs Summary Test Cells




Permit No.: T005-39514-00015




HAP Emission Factors

Benzene Toluene Xylene 1,3-Butadiene Formaldehyde Acetylaldehyde Acrolein PAH Biphenyl Methanol Hexane 2,2,4-Trimethylpentane Ethylbenzene Cumene MEK Propionaldehyde Styrene

Diesel Fuel <600 lb/MMBtu 9.33E-04 4.09E-04 2.85E-04 3.91E-05 1.18E-03 7.67E-04 9.25E-05 1.68E-04

Diesel Fuel >600 lb/MMBtu 7.76E-04 2.81E-04 1.93E-04 7.89E-05 2.52E-05 7.90E-06 1.68E-04

Natural Gas lb/MMBtu 4.40E-04 4.08E-04 1.84E-04 2.67E-04 5.28E-02 8.36E-03 5.14E-03 2.12E-04 2.50E-03 1.10E-03 2.50E-04

Gasoline lb/MMBtu 0.104 0.229 0.134 0.0351 0.0281 0.0137 0.00285 0.001 0.0426 0.00845 0.0966 0.051 0.00379 0.000303 0.0037 0.00258

Total HAPs

Diesel Fuel <600 lb/hp-hr 6.53E-06 2.86E-06 2.00E-06 2.74E-07 8.26E-06 5.37E-06 6.48E-07 1.18E-06 2.71E-05

Diesel Fuel >600 lb/hp-hr 5.43E-06 1.97E-06 1.35E-06 5.52E-07 1.76E-07 5.53E-08 1.18E-06 1.07E-05

Natural Gas lb/hp-hr 3.08E-06 2.86E-06 1.29E-06 1.87E-06 3.70E-04 5.85E-05 3.60E-05 1.48E-06 1.75E-05 7.70E-06 1.75E-06 5.02E-04

Gasoline lb/hp-hr 7.28E-04 1.60E-03 9.38E-04 2.46E-04 1.97E-04 9.59E-05 2.00E-05 7.00E-06 2.98E-04 5.92E-05 6.76E-04 3.57E-04 2.65E-05 2.12E-06 2.59E-05 1.81E-05 5.30E-03

Total HAPs

EU-04 LDTC4 500 HP 1.43E-02 6.27E-03 4.37E-03 5.99E-04 1.81E-02 1.18E-02 1.42E-03 2.58E-03 0.06








EU-09 LDD1 450 HP 1.29E-02 5.64E-03 3.93E-03 5.39E-04 1.63E-02 1.06E-02 1.28E-03 2.32E-03 0.05





EU-13 142.86 HP 4.09E-03 1.79E-03 1.25E-03 1.71E-04 5.17E-03 3.36E-03 4.05E-04 7.36E-04 0.02

EU-14 142.86 HP 4.09E-03 1.79E-03 1.25E-03 1.71E-04 5.17E-03 3.36E-03 4.05E-04 7.36E-04 0.02

EU-15 142.86 HP 4.09E-03 1.79E-03 1.25E-03 1.71E-04 5.17E-03 3.36E-03 4.05E-04 7.36E-04 0.02

EU-16 142.86 HP 4.09E-03 1.79E-03 1.25E-03 1.71E-04 5.17E-03 3.36E-03 4.05E-04 7.36E-04 0.02





EU-22 LDD6 675 HP 2.15E+00 4.74E+00 2.77E+00 7.26E-01 1.09E+00 2.84E-01 1.06E-01 2.07E-02 4.39E-03 8.82E-01 1.75E-01 2.00E+00 1.06E+00 7.84E-02 6.27E-03 7.66E-02 5.34E-02 15.66

EU-23-EMC1 605 HP 1.44E-02 7.57E-03 3.58E-03 4.95E-03 9.79E-01 1.55E-01 9.53E-02 3.12E-03 3.93E-03 4.64E-02 2.04E-02 4.64E-03 1.33

EU-24-EMC2 1500 HP 3.57E-02 1.88E-02 8.88E-03 1.23E-02 2.43E+00 3.84E-01 2.36E-01 7.73E-03 9.75E-03 1.15E-01 5.06E-02 1.15E-02 3.30

Total HAP Emissions 2.46 4.88 2.86 0.75 4.82 1.03 0.46 0.08 0.02 1.04 0.25 2.02 1.06 0.08 0.01 0.08 0.05 21.34

Assume that the HAP emissions for biodiesel and JP-8 are equivelent to the HAP emission factors for diesel fuel; therefore, the HAP emissions for these fuels does not affect the worst case HAP emissions.

To convert the lb/MMBtu emission factor to lb/hp-hr, multiply the emission factor by 0.007. (7000 Btu/hp-hr)

HAP PTE = Maximum Capcity (HP) x Emission Factor (lb/ hp-hr) x 8760 hrs/yr x 1 ton/ 2000 lbs

Formaldehyde is the single highest HAP. the conversion for gasoline must not be right...

HAP Emissions for EU-22 LDD6 prior to modification:

Benzene Toluene Xylene 1,3-Butadiene Formaldehyde Acetylaldehyde Acrolein PAH Total HAPs

EU-22 LDD6 1.61E-02 5.82E-03 3.99E-03 0.00E+00 1.63E-03 5.22E-04 1.63E-04 3.48E-03 3.17E-02


HAPs Summary Boilers and Emer G




Permit No.: T005-39514-00015




HAPs Emission - Entire Source

Pollutant Internal Combustion External Combustion Total HAPs (tons/yr)

<600 HP >600 HP < 99 MMBtu/hr BoilersHeaters and

AMUs

Emergency

GeneratorsBenzene 6.53E-06 lb/hp/hr 9.33E-04 lb/MMBtu/hr 5.43E-06 lb/hp-hr 2.1E-03 lb/MMCF 2.56E-04 8.08E-04 1.77E-01 1.78E-01 Benzene

Toluene 2.86E-06 lb/hp/hr 4.09E-04 lb/MMBtu/hr 1.97E-06 lb/hp-hr 3.4E-03 lb/MMCF 4.15E-04 1.31E-03 7.76E-02 7.93E-02 Toluene

Xylene 2.00E-06 lb/hp/hr 2.85E-04 lb/MMBtu/hr 1.35E-06 lb/hp-hr 5.41E-02 5.41E-02 Xylene

1,3-Butadiene 2.74E-07 lb/hp/hr 3.91E-05 lb/MMBtu/hr 7.42E-03 7.42E-03 1,3-Butadiene

Formaldehyde 8.26E-06 lb/hp/hr 1.18E-03 lb/MMBtu/hr 5.52E-07 lb/hp-hr 7.5E-02 lb/MMCF 9.15E-03 2.89E-02 2.24E-01 2.62E-01 Formaldehyde

Acetylaldehyde 5.37E-06 lb/hp/hr 7.67E-04 lb/MMBtu/hr 1.76E-07 lb/hp-hr 1.46E-01 1.46E-01 Acetylaldehyde

Acrolein 6.48E-07 lb/hp/hr 9.25E-05 lb/MMBtu/hr 5.52E-08 lb/hp-hr 1.75E-02 1.75E-02 Acrolein

PAH 1.18E-06 lb/hp/hr 1.68E-04 lb/MMBtu/hr 1.48E-06 lb/hp-hr 3.19E-02 3.19E-02 PAH

Dichlorobenzene 1.2E-03 lb/MMCF 1.46E-04 4.62E-04 6.08E-04 Dichlorobenzene

Hexane 1.8E+00 lb/MMCF 2.20E-01 6.93E-01 9.12E-01 Hexane

Lead 5.0E-04 lb/MMCF 6.10E-05 1.92E-04 2.53E-04 Lead

Cadmium 1.1E-03 lb/MMCF 1.34E-04 4.23E-04 5.58E-04 Cadmium

Chromium 1.4E-03 lb/MMCF 1.71E-04 5.39E-04 7.10E-04 Chromium

Manganese 3.8E-04 lb/MMCF 4.64E-05 1.46E-04 1.93E-04 Manganese

Nickel 2.1E-03 lb/MMCF 2.56E-04 8.08E-04 1.06E-03 Nickel

Total HAPs 0.23 0.73 0.73 1.69

Single Worst HAP 0.22 0.69 0.22 0.91

Hexane Hexane Formaldehyde Hexane

HAP PTE = Maximum Capcity x Emission Factor x 8760 hrs/yr x 1 ton/ 2000 lbs


Internal Combustion EF




Permit No.: T005-39514-00015




Sulfur Content (S): 0.05

Emission Factors for Emergency Generators and Test Cells


Diesel 0.297 lb/gal

Site Specific Stack Test

Diesel <600 HP 0.002 lb/hp-hr 0.002 lb/hp-hr 0.002 lb/hp-hr 0.002 lb/hp-hr 0.031 lb/hp-hr 0.003 lb/hp-hr 0.007 lb/hp-hr


Diesel >600 HP 0.001 lb/hp-hr 0.0004 lb/hp-hr 0.0004 lb/hp-hr 0.0004 lb/hp-hr 0.024 lb/hp-hr 0.001 lb/hp-hr 0.006 lb/hp-hr


Gasoline Any 0.00021 lb/hp-hr 0.00021 lb/hp-hr 0.00021 lb/hp-hr 0.000591 lb/hp-hr 0.011 lb/hp-hr 0.0216 lb/hp-hr 0.00696 lb/hp-hr


Diesel <600 HP 0.310 lb/MMBtu 0.310 lb/MMBtu 0.310 lb/MMBtu 0.290 lb/MMBtu - - 0.360 lb/MMBtu 0.950 lb/MMBtu


Diesel >600 HP 0.100 lb/MMBtu 0.057 lb/MMBtu 0.056 lb/MMBtu 0.051 lb/MMBtu - - 0.090 lb/MMBtu 0.850 lb/MMBtu


Natural Gas 0.0000771 lb/MMBtu 0.00999 lb/MMBtu 0.00999 lb/MMBtu 0.000588 lb/MMBtu 4.080 lb/MMBtu 0.118 lb/MMBtu 0.317 lb/MMBtu


Gasoline Any 0.10 lb/MMBtu 0.10 lb/MMBtu 0.10 lb/MMBtu 0.084 lb/MMBtu 1.63 lb/MMBtu 3.03 lb/MMBtu 0.99 lb/MMBtu


Diesel <600 HP 0.042 lb/gal 0.042 lb/gal 0.042 lb/gal 0.040 lb/gal - - 0.049 lb/gal 0.130 lb/gal


Diesel >600 HP 0.014 lb/gal 0.008 lb/gal 0.008 lb/gal 0.0069 lb/gal - - 0.012 lb/gal 0.116 lb/gal


Biodiesel <600 HP 0.039 lb/gal 0.039 lb/gal 0.039 lb/gal 0.037 lb/gal 0.273 lb/gal 0.045 lb/gal 0.120 lb/gal


Biodiesel >600 HP 0.013 lb/gal 0.007 lb/gal 0.007 lb/gal 0.0064 lb/gal 0.273 lb/gal 0.011 lb/gal 0.107 lb/gal


JP-8 <600 HP 0.042 lb/gal 0.042 lb/gal 0.042 lb/gal 0.039 lb/gal 0.293 lb/gal 0.049 lb/gal 0.128 lb/gal


JP-8 >600 HP 0.014 lb/gal 0.008 lb/gal 0.008 lb/gal 0.007 lb/gal 0.293 lb/gal 0.012 lb/gal 0.115 lb/gal


Natural Gas 0.08 lb/MMSCF 10.19 lb/MMSCF 10.19 lb/MMSCF 0.60 lb/MMSCF 4161.60 lb/MMSCF 120.36 lb/MMSCF 323.34 lb/MMSCF

Converted to lb/MMSCF using HHV 1020 MMBTU/MMSCF

Gasoline 0.013 lb/gal 0.013 lb/gal 0.013 lb/gal 0.01092 lb/gal 0.2119 lb/gal 0.3939 lb/gal 0.1287 lb/gal


Methodology:

The NOx emission factor (lb/gal) is based on stack testing performed by the source.

The first set of emission factors for diesel fired engines greater than 600 HP and less than 600 HP are from AP-42. Referneces to the Tables in which the emission factors

are listed can be found in the table under the emission factor.

The Biodiesel and JP-8 emission factors for NOx are converted from the stack testing results using the ratio of the High Heat Value for diesel and the High Heat Value for

either Biodiesel or JP-8 fuels. Emission Factor (lb/gal) = NOx Emission Factor for Diesel (lb/gal) * High Heat Value of Diesel (lb/gal) / High heat Value of JP-8 (lb/gal)

Emission Factor (lb/gal) = AP-42 Emission Factor (lb/MMBtu) * High Heat Value for Fuel (MMBtu/gal)

Emission Factor for SO2 (lb/MMBtu) = 1.01 x Sulfur Content (wt%)


Large Test Cells




Permit No.: T005-39514-00015


Significant Permit Modification No.: 005-41384-00015Permit Writer: Sommer Cochran

Diesel-fired Test Cell > 600 HP

Emission Factors PM PM10 PM2.5 SO2 NOx VOC CO Heat Content of Fuel

Diesel Fuel (lb/gal) 0.014 0.008 0.008 0.0069 0.297 0.012 0.116 Diesel Fuel 0.137 (MMBtu/gal)

Bio Diesel (lb/gal) 0.013 0.007 0.007 0.0064 0.273 0.011 0.107 Bio Diesel 0.126 (MMBtu/gal)

JP-8 (lb/gal) 0.014 0.008 0.008 0.007 0.293 0.012 0.115 JP-8 0.135 (MMBtu/gal)

Natural Gas (lb/MMSCF) 0.08 10.19 10.19 0.60 4161.60 120.36 323.34 Natural Gas 1020 (MMBtu/MMSCF)

Gasoline (lb/gal) 0.013 0.013 0.013 0.01092 0.2119 0.3939 0.1287 Gasoline 0.130 (MMBtu/gal)

Containerized Test CellMaximum Hourly

Output

Maximum Annual Fuel


EU-22 LDD6 PM PM10 PM2.5 SO2 NOx VOC CO



JP-8 675 HP 306600 gal/yr 2.15 1.23 1.23 1.07 44.92 1.84 17.63


Gasoline 675 HP 318392 gal/yr 2.07 2.07 2.07 1.74 33.73 62.71 20.49


Maximum Hourly

Output

Maximum Annual Fuel

Usage





JP-8 605 HP 274804 gal/yr 1.92 1.10 1.10 0.96 40.26 1.65 15.80



Maximum Hourly

Output

Maximum Annual Fuel

Usage





JP-8 1500 HP 681333 gal/yr 4.77 2.73 2.73 2.38 99.82 4.09 39.18



Methodology:

For liquid fuels:

Heat Content of Fuel (MMBtu/gal) = Heating Value (Btu/lb) * 1 MMBtu/ 1000000 Btu * Fuel Density (lb/gal)

Maximum Annual Fuel Usage (gal/yr) = Maximum Hourly Output (HP) x 7000 Btu/HP-hr x 1 MMBtu/ 1,000,000 Btu x 8760 hrs/yr ÷ Heat Content of Fuel (MMBtu/gal)

PTE (tons/yr) = Emission Factor (lb/gal) x Maximum Fuel Usage (gal/yr) x 1 ton/ 2000 lbs

For gasous fuels:

Heat Content of Fuel (MMBtu/MMSCF) = 1020 Btu/scf x 1 MMBtu/ 1000000 Btu x 1000000 scf/ MMSCF

PTE (tons/yr) = Emission Factor (lb/MMSCF) x Maximum Fuel Usage (MMSCF/yr) x 1 ton/ 2000 lbs


Cell


Cell


Small Test Cells




Permit No.: T005-39514-00015




Diesel-fired Test Cell < 600 HP

Emission Factors (lb/gal) PM PM10 PM2.5 SO2 NOx VOC CO Heating Values (MMBtu/gal)

Diesel Fuel 0.042 0.042 0.042 0.04 0.297 0.049 0.13 Diesel Fuel 0.137

Bio Diesel 0.039 0.039 0.039 0.037 0.273 0.045 0.12 Bio Diesel 0.126

JP-8 0.042 0.042 0.042 0.039 0.293 0.049 0.128 JP-8 0.135

Gasoline 0.013 0.013 0.013 0.01092 0.2119 0.3939 0.1287 Gasoline 0.130

Maximum Hourly

Output

Maximum Annual Fuel




Bio Diesel 500 HP 243333.3 gal/yr 4.75 4.75 4.75 4.50 33.22 5.48 14.60

JP-8 500 HP 227111.1 gal/yr 4.77 4.77 4.77 4.43 33.27 5.56 14.54



Cycle Test CellsMaximum Hourly

Output

Maximum Annual Fuel





JP-8 450 HP 204400 gal/yr 4.29 4.29 4.29 3.99 29.94 5.01 13.08



Cold Test CellsMaximum Hourly

Output

Maximum Annual Fuel



Diesel Fuel 142.86 HP 63942.88 gal/yr 1.34 1.34 1.34 1.28 9.50 1.57 4.16

Bio Diesel 142.86 HP 69525.2 gal/yr 1.36 1.36 1.36 1.29 9.49 1.56 4.17

JP-8 142.86 HP 64890.19 gal/yr 1.36 1.36 1.36 1.27 9.51 1.59 4.15



PTE = Emission Factor (lb/gal) x Maximum Annual Fuel Usage (gal/yr) x 1 ton/ 2000 lbs

The emissions for each individual cell are calculated in the table, the worse case emissions for each pollutants are multipled by the number of engines.

Fuel Test Cells,

Production Test Cells,

and Hot Test Cells


Boilers




Permit No.: T005-39514-00015




HHV (MMBtu/MMSCF) Maximum Emission Factors (lb/MMCF)

1020 Capacity PM PM10 PM2.5 SO2 NOx VOC CO

For Natural Gas (MMBtu/hr) 1.90 7.60 7.60 0.60 100 5.50 84

Emission Unit Emissions (tons/yr)

Vertical Fired Tube Steam Boiler

B1 2.100 0.02 0.07 0.07 0.01 0.90 0.05 0.76

B2 2.100 0.02 0.07 0.07 0.01 0.90 0.05 0.76

Hot Water Boiler

Raypak-61 Boiler 1 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Raypak-61 Boiler 2 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Raypak-61 Boiler 3 1.500 0.01 0.05 0.05 0.00 0.64 0.04 0.54

Aerco 96 Boiler 1 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Aerco 96 Boiler 2 0.900 0.01 0.03 0.03 0.00 0.39 0.02 0.32

Aerco 96 Boiler 3 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Aerco 96 Boiler 4 0.960 0.01 0.03 0.03 0.00 0.41 0.02 0.35

Boilers

Raypak-72 Boiler 1 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Raypak-72 Boiler 2 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Raypak-72 Boiler 3 1.260 0.01 0.04 0.04 0.00 0.54 0.03 0.45

Lochinvar 1 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 2 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 3 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 4 2.075 0.02 0.07 0.07 0.01 0.89 0.05 0.75

Lochinvar 5 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 6 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 7 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 8 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Lochinvar 9 0.400 0.003 0.01 0.01 0.00 0.17 0.01 0.14

Cleaver Brooks 1 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

Cleaver Brooks 2 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

Cleaver Brooks 3 0.620 0.01 0.02 0.02 0.00 0.27 0.01 0.22

(MMBtu/hr) PM PM10 PM2.5 SO2 NOx VOC CO

Total 28.42 0.23 0.93 0.93 0.07 12.20 0.67 10.25

Methodology

*PM emission factor is filterable PM only. PM10 emission factor is filterable and condensable PM10 combined.

PM2.5 emission factor is filterable and condensable PM2.5 combined.

**Emission Factors for NOx: Uncontrolled = 100, Low NOx Burner = 50, Low NOx Burners/Flue gas recirculation = 32

All emission factors are based on normal firing.

MMBtu = 1,000,000 Btu

MMCF = 1,000,000 Cubic Feet of Gas

Emission Factors are from AP 42, Chapter 1.4, Tables 1.4-1, 1.4-2, 1.4-3, SCC #1-02-006-02, 1-01-006-02, 1-03-006-02, and 1-03-006-03

Potential Throughput (MMCF) = Heat Input Capacity (MMBtu/hr) x 8,760 hrs/yr x 1 MMCF/1,020 MMBtu

Emission (tons/yr) = Throughput (MMCF/yr) x Emission Factor (lb/MMCF)/2,000 lb/ton


Air Make Up Units




Permit No.: T005-39514-00015




Emission Unit Heat Input Emission Unit Heat Input Emission Unit Heat Input

Air Make Up Units (MMBtu/hr) B82 Dock Unit 1 0.320 Ventilation Inlet 1 0.823







AHAP 7 2.000 CAU-LDTC 0.937 Viking Chip 4 0.320




AHAP 11 1.000 Cell Ventilation 4 0.550 Viking Perimeter 1 0.160

AHAP 12 1.000 Cell Ventilation 5 Viking Perimeter 2 0.160

AHU Hybrid 0.800 Cell Ventilation 6 Viking Perimeter 3 0.160







B30 RTU 0.090 electric DOC test rig 0.000 Viking Perimeter 10 0.160

B42 Unit 0.320 LDD 1 3.490 Viking Perimeter 11 0.160

B47 1.200 LDD 2 3.490 Viking Perimeter 12 0.160







B72 Perimeter 1 0.160 LDD 9 2.670 Viking Perimeter 19 0.160

B72 Perimeter 2 0.160 LDD AHU 12 0.030 Viking Perimeter 20 0.160





B73 5 1.039 Roll Up DR73 3 1.100

B73 6 1.039 Roll Up DR73 4 1.100 Total Maximum Heat Input

B73 Conference 0.056 Roll Up DR73 5 1.100 89.633 MMBtu/hr

Summary of Potential Emissions from Sources of Natural Gas Combustion


Emission Factor

(lnb/MMCF)1.9 7.6 7.6 0.6 100 5.5 84

PTE (tons/yr) 0.73 2.93 2.93 0.23 38.49 2.12 32.33

Emission Factors are from AP 42, Chapter 1.4, Tables 1.4-1, 1.4-2, 1.4-3, SCC #1-02-006-02,

1-01-006-02, 1-03-006-02, and 1-03-006-03. Based on normal firing.

Potential Emissions (tons/yr) = Heat Input Capacity (MMBtu/hr) * 8760 hrs/yr *1 MMCF/ 1020 MMBtu

* Emission Factor (lb/MMSCF)/* 1 ton/ 2000lbs

2.700

2.700


Emergency Generators




Permit No.: T005-39514-00015




Potential to Emit (tons/yr)


Diesel-fired Emergency Generators

Genset 1 380 HP 0.21 0.21 0.21 0.20 2.95 0.07 0.64

Genset 2 755 HP 0.13 0.08 0.08 0.08 4.53 0.13 1.04

Diesel-fired Stationary Fire Pump Engines

CEP 171 HP 0.09 0.09 0.09 0.09 1.33 0.11 0.29

Total Emissions 0.44 0.38 0.38 0.37 8.80 0.31 1.96

Total Engine Output (HP) engines <600 HP 551 HP

Total Engine Output (HP) engines >600 HP 755 HP

Total Engine Power (MMBtu/hr) 0.00 MMBtu/hr

Methodology:

Potential Emissions (tons/yr) = Maximum Output (HP) * Internal Combustion Emission Factor (lb/hp-hr)

* 500 Operating hrs/yr * 1 ton/ 2000 lbs

Emission Factors are from AP-42 Chapter 3. See page 2 for detailed documentation.


Insignificant Activities




Permit No.: T005-39514-00015




DegreasersUsage Density VOC Content VOC

(gal/yr) (lb/gal) (wt%) (ton/yr)

Solvent 145 8.34 100% 0.60

TrimmersParticulate emissions from the trimmers are negligible.

Grinding and MachiningEmission Unit Usage Density VOC Content VOC PTE



Methodology:

VOC PTE (tons/yr) = Usage (gal/yr) x Density (lb/gal) x VOC Content (wt%) x 1 ton/ 2000 lbs

The Grinding and Machining Operations use an aquous solution and mist collectors. Particulate emissions are negligible.

Cooling Towers

Emissions Unit

Circulation

Rate (gal/hr)Drift (%)

PM

Emission

s Factor

(lb/gal)

TDS (ppm)

PM

Emissions

(tons/yr)

PM10

Emmisions

(ton/yr)

PM2.5

Emmisions

(ton/yr)

Cooling Tower 162000 0.02 0.019 1500 0.17 0.17 0.17

Total 0.17 0.17 0.17

Methodology:

Potential Emissions (tons/yr) = Circulation Rate (gal/hr) * Drift (%) * Emission Factor (lb PM/ 10000 gal)

* TDS ratio (2000 ppm / 12000 ppm) *8760 hrs/yr * 1 ton/ 2000 lb

Emission Factor from AP-42, Table 13.4-1. Factors imply a TDS content of 12,000 ppm.

Drift (%) is the percentage of water droplets that become entrained in the cooling tower exit air stream.

PM = PM10 = PM2.5

WeldingEmission Factors PM PM10 PM2.5 Mn

(lb pollutant/ lb wire) 0.0055 0.0055 0.0055 0.0005

ID Maximum Capacity Potential Emissions (ton/yr)

TIG 19.5 lb wire/hr 0.47 0.47 0.47 0.04

MIG 11.25 lb wire/hr 0.27 0.27 0.27 0.02

MIG 11.25 lb wire/hr 0.27 0.27 0.27 0.02

Total 1.01 1.01 1.01 0.09

Mehodolgy:

Potential Emissions (tons/yr) = Max Capacity (lb/hr) * Emission Factor (lb/lb) * 8760 hrs/yr * 1 ton/ 2000 lb

Battery AssemblyPM, PM10, PM2.5, and VOC emissions from the Battery Assembly Operation are negligible.

Paint Booth

DensityVOC

Content

Solid

ContentUsage Rate PM PM10 PM2.5 VOC

(lb/gal) (wt%) (wt%) (gal/unit) (unit/hr) (tons/yr) (tons/yr) (tons/yr) (tons/yr)

Block Coating 8.91 4% 37% 0.4 0.3 0.86 0.86 0.86 0.20

Head Coating 8.91 4% 37% 0.2 0.3 0.43 0.43 0.43 0.10

Total Emissions 1.29 1.29 1.29 0.30

Emissions after control (dry filters) 99% control efficiency 0.01 0.01 0.01

Surface Coating Usage = 4.32 gallons/day VOC Emissions = 1.64 lbs/day

Metholdology:

Potential VOC Emissions (tons/yr) = Usage Rate (gal/hr) * Density (lb/gal) * VOC Content (wt%) * 1 ton/2000 lbs * 8760 hrs/yr

Potential PM Emissions (tons/yr) = Usage Rate (gal/hr) * Density (lb/gal) * Solid Content (wt%) * (1 - Transfer Efficiency (50%)

*1 ton/ 2000 lbs * 8760 hrs/yr

Fuel Storage Tanks Maximum Throughput (gallons/yr) VOC Working Losses VOC Emissions (tons/yr) Total (tpy)


Tank 5 15,800 gal x 50 turnovers 790000 0.09 0.00005 1.01



Other VOC and HAP Storage Containers VOC/HAP Emissions < 1

Methodology:

US EPA TANKS Version 4.09 PTE (tons/yr) = VOC Working Losses (lbs/yr) x 8760 hrs/yr x 1 ton/2000 lbs


Paved Roads




Permit No.: T005-39514-00015




The following calculations determine the amount of emissions created by paved roads, based on 8,760 hours of use and AP-42, Ch 13.2.1 (1/2011).

Vehicle Informtation (provided by source)

Type

Maximum

number of

vehicles per day

Number of one-

way trips per day

per vehicle

Maximum trips

per day (trip/day)

Maximum

Weight Loaded

(tons/trip)

Total Weight

driven per day

(ton/day)

Maximum one-

way distance

(feet/trip)

Maximum one-

way distance

(mi/trip)

Maximum one-

way miles

(miles/day)

Maximum one-

way miles

(miles/yr)

Vehicle (entering plant) (one-way trip) 5.0 1.0 5.0 40.0 200.0 10000 1.894 9.5 3456.4

Vehicle (leaving plant) (one-way trip) 5.0 1.0 5.0 20.0 100.0 10000 1.894 9.5 3456.4

Totals 10.0 300.0 18.9 6912.9

Average Vehicle Weight Per Trip = 30.0 tons/trip

Average Miles Per Trip = 1.89 miles/trip

Unmitigated Emission Factor, Ef = [k * (sL)^0.91 * (W)^1.02] (Equation 1 from AP-42 13.2.1)

PM PM10 PM2.5

where k = 0.011 0.0022 0.00054 lb/VMT = particle size multiplier (AP-42 Table 13.2.1-1)

W = 30.0 30.0 30.0 tons = average vehicle weight (provided by source)

sL = 9.7 9.7 9.7 g/m^2 = silt loading value for paved roads at iron and steel production facilities - Table 13.2.1-3)

Taking natural mitigation due to precipitation into consideration, Mitigated Emission Factor, Eext = E * [1 - (p/4N)] (Equation 2 from AP-42 13.2.1)

Mitigated Emission Factor, Eext = Ef * [1 - (p/4N)]

where p = 125 days of rain greater than or equal to 0.01 inches (see Fig. 13.2.1-2)

N = 365 days per year

PM PM10 PM2.5

Unmitigated Emission Factor, Ef = 2.793 0.559 0.1371 lb/mile

Mitigated Emission Factor, Eext = 2.554 0.511 0.1254 lb/mile

Dust Control Efficiency = 50% 50% 50% (pursuant to control measures outlined in fugitive dust control plan)

Process

Mitigated

PTE of PM

(Before Control)

(tons/yr)

Mitigated

PTE of PM10

(Before Control)

(tons/yr)

Mitigated

PTE of PM2.5

(Before Control)

(tons/yr)

Mitigated

PTE of PM

(After Control)

(tons/yr)

Mitigated

PTE of PM10

(After Control)

(tons/yr)

Mitigated

PTE of PM2.5

(After Control)

(tons/yr)

Vehicle (entering plant) (one-way trip) 4.41 0.88 0.22 2.21 0.44 0.11

Vehicle (leaving plant) (one-way trip) 4.41 0.88 0.22 2.21 0.44 0.11

Totals 8.83 1.77 0.43 4.41 0.88 0.22

Methodology Abbreviations

Total Weight driven per day (ton/day) = [Maximum Weight Loaded (tons/trip)] * [Maximum trips per day (trip/day)] PM = Particulate Matter

Maximum one-way distance (mi/trip) = [Maximum one-way distance (feet/trip) / [5280 ft/mile] PM10 = Particulate Matter (<10 um)

Maximum one-way miles (miles/day) = [Maximum trips per year (trip/day)] * [Maximum one-way distance (mi/trip)] PM2.5 = Particle Matter (<2.5 um)

Average Vehicle Weight Per Trip (ton/trip) = SUM[Total Weight driven per day (ton/day)] / SUM[Maximum trips per day (trip/day)] PTE = Potential to Emit

Average Miles Per Trip (miles/trip) = SUM[Maximum one-way miles (miles/day)] / SUM[Maximum trips per year (trip/day)]

Unmitigated PTE (tons/yr) = [Maximum one-way miles (miles/yr)] * [Unmitigated Emission Factor (lb/mile)] * (ton/2000 lbs)

Mitigated PTE (Before Control) (tons/yr) = [Maximum one-way miles (miles/yr)] * [Mitigated Emission Factor (lb/mile)] * (ton/2000 lbs)

Mitigated PTE (After Control) (tons/yr) = [Mitigated PTE (Before Control) (tons/yr)] * [1 - Dust Control Efficiency]



(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

November 12, 2019 Mr. David Wehrkamp Cummins, Inc. Columbus Engine Plant (CEP) 500 Central Avenue Columbus, Indiana 47201 Re: Public Notice Cummins, Inc. Columbus Engine Plant (CEP) Permit Level: Title V SSM (Minor PSD) and Title V SPM Permit Number: 005-41279-00015 and 005-41384-00015 Dear Mr. Wehrkamp: Enclosed is a copy of your draft Title V Significant Source Modification (Minor PSD) and your draft Title V Significant Permit Modification, Technical Support Document, emission calculations, and the Public Notice. The Public Notice period will begin the date the Notice is published on the IDEM Official Public Notice website. Publication has been requested and is expected within 2-3 business days. You may check the exact Public Notice begins and ends date here: https://www.in.gov/idem/5474.htm Please note that as of April 17, 2019, IDEM is no longer required to publish the notice in a newspaper. OAQ has submitted the draft permit package to the Bartholomew County Public Library, 536 5th Street in Columbus, Indiana. As a reminder, you are obligated by 326 IAC 2-1.1-6(c) to place a copy of the complete permit application at this library no later than ten (10) days after submittal of the application or additional information to our department. We highly recommend that even if you have already placed these materials at the library, that you confirm with the library that these materials are available for review and request that the library keep the materials available for review during the entire permitting process. Please review the enclosed documents carefully. This is your opportunity to comment on the draft permit and notify the OAQ of any corrections that are needed before the final decision. Questions or comments about the enclosed documents should be directed to Mrs. Iryn Calilung, Indiana Department of Environmental Management, Office of Air Quality, 100 N. Senate Avenue, Indianapolis, Indiana, 46204 or call (800) 451-6027, and ask for extension 3-5692 or dial (317) 233-5692. Sincerely, John F. Jackson John F. Jackson Permits Branch Office of Air Quality

Enclosures PN Applicant Cover Letter 4/12/19




(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

November 12, 2019 To: Bartholomew County Public Library From: Jenny Acker, Branch Chief Permits Branch Office of Air Quality Subject: Important Information to Display Regarding a Public Notice for an Air Permit

Applicant Name: Cummins, Inc. Columbus Engine Plant (CEP) Permit Number: 005-41279-00015 and 005-41384-00015 Enclosed is a copy of important information to make available to the public. This proposed project is regarding a source that may have the potential to significantly impact air quality. Librarians are encouraged to educate the public to make them aware of the availability of this information. The following information is enclosed for public reference at your library: • Notice of a 30-day Period for Public Comment • Draft Permit and Technical Support Document You will not be responsible for collecting any comments from the citizens. Please refer all questions and request for the copies of any pertinent information to the person named below. Members of your community could be very concerned in how these projects might affect them and their families. Please make this information readily available until you receive a copy of the final package. If you have any questions concerning this public review process, please contact Joanne Smiddie-Brush, OAQ Permits Administration Section at 1-800-451-6027, extension 3-0185. Questions pertaining to the permit itself should be directed to the contact listed on the notice.

Enclosures PN Library updated 4/2019



(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

Notice of Public Comment November 12, 2019 Cummins, Inc. Columbus Engine Plant (CEP) 005-41279-00015 and 005-41384-00015 Dear Concerned Citizen(s): You have been identified as someone who could potentially be affected by this proposed air permit. The Indiana Department of Environmental Management, in our ongoing efforts to better communicate with concerned citizens, invites your comment on the draft permit. Enclosed is a Notice of Public Comment, which has posted on IDEM’s Public Notice website at https://www.in.gov/idem/5474.htm. The application and supporting documentation for this proposed permit have been placed at the library indicated in the Notice. These documents more fully describe the project, the applicable air pollution control requirements and how the applicant will comply with these requirements. If you would like to comment on this draft permit, please contact the person named in the enclosed Public Notice. Thank you for your interest in the Indiana’s Air Permitting Program. Please Note: If you feel you have received this Notice in error, or would like to be removed from the Air Permits mailing list, please contact Patricia Pear with the Air Permits Administration Section at 1-800-451-6027, ext. 3-6875 or via e-mail at [email protected]. If you have recently moved and this Notice has been forwarded to you, please notify us of your new address and if you wish to remain on the mailing list. Mail that is returned to IDEM by the Post Office with a forwarding address in a different county will be removed from our list unless otherwise requested.

Enclosure PN AAA Cover Letter 4/12/2019




(800) 451-6027 • (317) 232-8603 • www.idem.IN.gov



Recycled Paper

AFFECTED STATE NOTIFICATION OF PUBLIC COMMENT PERIOD DRAFT INDIANA AIR PERMIT

November 12, 2019 A 30-day public comment period has been initiated for: Permit Number: 005-41279-00015 and 005-41384-00015 Applicant Name: Cummins, Inc. Columbus Engine Plant (CEP) Location: Columbus, Bartholomew County, Indiana The public notice, draft permit and technical support documents can be accessed via the IDEM Air Permits Online site at: http://www.in.gov/ai/appfiles/idem-caats/ Questions or comments on this draft permit should be directed to the person identified in the public notice by telephone or in writing to:

Indiana Department of Environmental Management Office of Air Quality, Permits Branch 100 North Senate Avenue Indianapolis, IN 46204

Questions or comments regarding this email notification or access to this information from the EPA Internet site can be directed to Chris Hammack at [email protected] or (317) 233-2414.

Affected States Notification 1/9/2017


FACSIMILIE OF PS Form 3877

Mail Code 61-53

IDEM Staff JJACKSON 11/12/2019 (DRAFT) Cummins Inc Columbus Engine Plant 005-41279-00015 & 005-41384-00015

AFFIX STAMP HERE IF USED AS CERTIFICATE OF MAILING

Name and address of Sender ► Indiana Department of Environmental

Management Office of Air Quality – Permits Branch 100 N. Senate Indianapolis, IN 46204

Type of Mail:

CERTIFICATE OF MAILING ONLY

Line Article

Number Name, Address, Street and Post Office Address Postage Handing

Charges Act. Value (If Registered)

Insured Value

Due Send if COD

R.R. Fee

S.D. Fee S.H. Fee

Rest. Del. Fee Remarks

1 David Wehrkamp Cummins Inc Columbus Engine Plant 500 Central Ave Columbus IN 47201 (Source CAATS) 2 Jeff Hurd Plant Manager Cummins Inc Columbus Engine Plant 500 Central Ave Columbus IN 47201 (RO CAATS) 3 Columbus City Council and Mayors Office 123 Washington St Columbus IN 47201 (Local Official) 4 Mr. Lcnfc 1039 Sycamore St Columbus IN 47201 (Affected Party) 5 Bartholomew County Public Library 536 Fifth St. Columbus IN 47201-6225 (Library) 6 Bartholomew County Commissioners 440 Third Street Columbus IN 47202 (Local Official) 7 Mr. Jean Terpstra 30225 Adams Ln Westlake OH 44145 (Affected Party) 8 Terry Lowe 450 Hurricane St Franklin IN 46131 (Affected Party) 9 Mr. Charles Mitch 30225 Adams Ln Westlake OH 44145 (Affected Party) 10 Bartholomew County Health Department 440 3rd Street, Suite 303 Columbus IN 47201 (Health Department) 11 Bernard Paul B Paul Consulting, LLC 285 Spring Drive Zionsville IN 46077 (Consultant) 12 Kenneth K Arnholt Trust\Berneice M Arnholt 2850 N Indianapolis Rd Columbus IN 47201 (Affected Party) 13 Kevin Green Greensburg Daily News 135 S Franklin St Greensburg IN 47240 (Affected Party) 14 15

Total number of pieces Listed by Sender

Total number of Pieces Received at Post Office

Postmaster, Per (Name of Receiving employee)

The full declaration of value is required on all domestic and international registered mail. The maximum indemnity payable for the reconstruction of nonnegotiable documents under Express Mail document reconstructing insurance is $50,000 per piece subject to a limit of $50, 000 per occurrence. The maximum indemnity payable on Express mil merchandise insurance is $500. The maximum indemnity payable is $25,000 for registered mail, sent with optional postal insurance. See Domestic Mail Manual R900, S913, and S921 for limitations of coverage on inured and COD mail. See International Mail Manual for limitations o coverage on international mail. Special handling charges apply only to Standard Mail (A) and Standard Mail (B) parcels.

FACSIMILIE OF PS Form 3877

notice of 30-day period for public commentpermits.air.idem.in.gov/41279d.pdfindiana department of...

Documents