DAQ-2024-008508

DAQE-AN141260002-24

{{$d1 }}

Travis Bawcum
AT&T Communications of the Mountain States, Incorporated
1311 South Akard Street, 12th Floor
Dallas, TX 75202
[e-mail]

Dear Mr. Bawcum:

Re: Approval Order: Minor Modification to Approval Order DAQE-AN0141260001-08 to Update
Equipment
Project Number: N141260002

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on February
7, 2024. AT&T Communications of the Mountain States, Incorporated must comply with the
requirements of this AO, all applicable state requirements (R307), and Federal Standards.

The project engineer for this action is Christine Bodell, who can be contacted at [phone] or
[e-mail]. Future correspondence on this AO should include the engineer's name as well as the
DAQE number shown on the upper right-hand corner of this letter. No public comments were received on
this action.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:CB:jg

cc: Bear River Health Department

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

June 12, 2024

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

{{#s=Sig_es_:signer1:signature}}
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}}
{{#d2=date1_es_:signer1:date:format(date, "mmmm d, yyyy"):align(center)}}

APPROVAL ORDER
DAQE-AN141260002-24
Minor Modification to Approval Order DAQE -AN0141260001-08 to
Update Equipment

Prepared By
Christine Bodell, Engineer
[phone]
[e-mail]

Issued to
AT&T Communications of the Mountain States, Incorporated –
Standby Generators

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
June 12, 2024
Division of Air Quality

TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 4
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 6
ACRONYMS ................................................................................................................................. 7

DAQE-AN141260002-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
AT&T Communications of the Mountain States,
Incorporated
AT&T Communications of the Mountain States,
Incorporated - Standby Generators

Mailing Address Physical Address
1311 South Akard Street, 12th Floor 1760 North Highway 38
Dallas, TX 75202 Brigham City, UT 84302

Source Contact UTM Coordinates
Name: Travis Bawcum 415,463 m Easting
Phone: [phone],599,323 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12

SIC code 4813 (Telephone Communications, Except Radiotelephone)

SOURCE INFORMATION
General Description
AT&T Communications of the Mountain States, Incorporated (AT&T) owns and operates a data center in
Brigham City, Box Elder County. The data center includes emergency generators that are used for
electricity production during periods when electric power from public utilities is interrupted.

NSR Classification
Minor Modification at Minor Source

Source Classification
Located in Salt Lake City, UT PM2.5 NAA
Box Elder County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
DAQE-AN141260002-24
Page 4

Project Description
AT&T has requested a modification to AO DAQE-AN0141260001-08 for the following changes:

- Remove three (3) 15 kW, diesel-fired emergency generators (listed as EGEN1-3 under Condition 7.A of
AO DAQE-AN0141260001-08);
- Add one (1) 40 kW, diesel-fired, emergency generator, and
- Update the capacity of the diesel storage tank (listed as Tank 1 under Condition 7.B of AO
DAQE-AN0141260001-08) from 4,000 gallons to 8,000 gallons.

SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent -3 405.00
Carbon Monoxide -0.01 1.93
Nitrogen Oxides -0.05 8.46
Particulate Matter - PM10 -0.01 0.26
Particulate Matter - PM2.5 -0.01 0.26
Sulfur Dioxide -0.17 0.00
Volatile Organic Compounds 0 0.27

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Generic HAPs (CAS #GHAPS) 1 8
Change (TPY) Total (TPY)
Total HAPs 0 0.00

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401-8]

DAQE-AN141260002-24
Page 5

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available to
the Director which may include, but is not limited to, monitoring results, opacity observations,
review of operating and maintenance procedures, and inspection of the source. All maintenance
performed on equipment authorized by this AO shall be recorded. [R307-401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories.
[R307-150]

I.8 The owner/operator shall submit documentation of the status of construction or modification to
the Director within 18 months from the date of this AO. This AO may become invalid if
construction is not commenced within 18 months from the date of this AO or if construction is
discontinued for 18 months or more. To ensure proper credit when notifying the Director, send
the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT

II.A THE APPROVED EQUIPMENT

II.A.1 AT&T Data Facility

II.A.2 Three (3) Emergency Generator Engines
Fuel: Diesel

One (1) 40 kW (54 horsepower (hp)) Generator Engine (New)
Manufactured: 1998
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

Two (2) 500 kW (671 hp) Generator Engines
Manufactured: Pre-2005
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

II.A.3 Three (3) Aboveground Fuel Storage Tanks
Content: Diesel

Tank 1: 8,000 gallons
Tank 2: 150 gallons
Tank 3: 150 gallons

DAQE-AN141260002-24
Page 6

SECTION II: SPECIAL PROVISIONS

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site-Wide Requirements
II.B.1.a The owner/operator shall not allow visible emissions from any stationary point or fugitive
emission source to exceed 20% opacity. [R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]

II.B.2 Emergency Engine Requirements
II.B.2.a The owner/operator shall not operate each emergency generator engine on site for more than 100
hours per calendar year for maintenance checks and readiness testing. Each emergency generator
engine on site may be operated for up to 50 hours per calendar year in non-emergency situations.
Any operation in non-emergency situations shall be counted as part of the 100 hours per calendar
year for maintenance and testing. There is no time limit on the use of the engines during
emergencies. [40 CFR 63, Subpart ZZZZ, R307-401-8]

II.B.2.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
documenting the operation of each emergency engine shall be kept in a log and shall include the
following:

A. The date the emergency engine was used.

B. The duration of the operation in hours.

C. The reason for the emergency engine usage.

[40 CFR 63, Subpart ZZZZ, R307-401-8]

II.B.2.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63, Subpart ZZZZ, R307-401-8]

II.B.2.b The owner/operator shall only use diesel fuel (e.g., fuel oil #1, #2, or diesel fuel oil additives) as
fuel in each emergency engine. [R307-401-8]

II.B.2.b.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur
diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8]

II.B.2.b.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain
records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel
fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD
requirements. [R307-401-8]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Supersedes AO DAQE-AN0141260001-08 dated November 13, 2008
Is Derived From Notice of Intent dated February 7, 2024
Incorporates Additional Information dated February 26, 2024

DAQE-AN141260002-24
Page 7

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document:

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by Environmental Protection Agency to classify
sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98,
Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal Division of Air Quality use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i)
GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818-
12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DAQE-IN141260002-24

May 2, 2024

Travis Bawcum
AT&T Communications of the Mountain States, Incorporated
1311 South Akard Street, 12th Floor
Dallas, TX 75202
[e-mail]

Dear Mr. Bawcum:

Re: Intent to Approve: Minor Modification to Approval Order DAQE-AN0141260001-08 to Update
Equipment
Project Number: N141260002

The attached document is the Intent to Approve (ITA) for the above-referenced project. The ITA is
subject to public review. Any comments received shall be considered before an Approval Order (AO) is
issued. The Division of Air Quality is authorized to charge a fee for reimbursement of the actual costs
incurred in the issuance of an AO. An invoice will follow upon issuance of the final AO.

Future correspondence on this ITA should include the engineer's name, Christine Bodell, as well as the
DAQE number as shown on the upper right-hand corner of this letter. Christine Bodell, can be reached at
[phone] or [e-mail], if you have any questions.

Sincerely,

{{$s }}

Alan D. Humpherys, Manager
New Source Review Section

ADH:CB:jg

cc: Bear River Health Department

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

INTENT TO APPROVE
DAQE-IN141260002-24
Minor Modification to Approval Order
DAQE-AN0141260001-08 to Update Equipment

Prepared By
Christine Bodell, Engineer
[phone]
[e-mail]

Issued to
AT&T Communications of the Mountain States, Incorporated –
Standby Generators

Issued On
May 2, 2024

{{$s }}

New Source Review Section Manager
Alan D. Humpherys
{{#s=Sig_es_:signer1:signature}}

TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
PUBLIC NOTICE STATEMENT............................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 7
ACRONYMS ................................................................................................................................. 8

DAQE-IN141260002-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
AT&T Communications of the Mountain States
Incorporated
AT&T Communications of the Mountain States,
Incorporated - Standby Generators

Mailing Address Physical Address
1311 South Akard Street, 12th Floor 1760 North Highway 38
Dallas, TX 75202 Brigham City, UT 84302

Source Contact UTM Coordinates
Name: Travis Bawcum 415,463 m Easting
Phone: [phone],599,323 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12

SIC code 4813 (Telephone Communications, Except Radiotelephone)

SOURCE INFORMATION
General Description
AT&T Communications of the Mountain States Incorporated (AT&T) owns/operates a data center in
Brigham City, Box Elder County. The data center includes emergency generators that are used for
electricity production during periods when electric power from public utilities is interrupted.

NSR Classification
Minor Modification at Minor Source

Source Classification
Located in Salt Lake City UT PM2.5 NAA
Box Elder County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

DAQE-IN141260002-24
Page 4

Project Description
AT&T has requested a modification to AO DAQE-AN0141260001-08 for the following changes:

- Remove three (3) 15 kW, diesel-fired emergency generators (listed as EGEN1-3 under Condition 7.A of
AO DAQE-AN0141260001-08);
- Add one (1) 40 kW, diesel-fired, emergency generator, and
- Update the capacity of the diesel storage tank (listed as Tank 1 under Condition 7.A of AO
DAQE-AN0141260001-08) from 4,000 gallons to 8,000 gallons.

SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent -3 405.00
Carbon Monoxide -0.01 1.93
Nitrogen Oxides -0.05 8.46
Particulate Matter - PM10 -0.01 0.26
Particulate Matter - PM2.5 -0.01 0.26
Sulfur Dioxide -0.17 0.00
Volatile Organic Compounds 0 0.27

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Generic HAPs (CAS #GHAPS) 1 8
Change (TPY) Total (TPY)
Total HAPs 0 0.00

PUBLIC NOTICE STATEMENT

The NOI for the above-referenced project has been evaluated and has been found to be consistent with the
requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be
constructed, installed, established, or modified prior to the issuance of an AO by the Director.

A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the
intent to approve will be published in the Box Elder News & Journal on May 8, 2024. During the public
comment period the proposal and the evaluation of its impact on air quality will be available for the
public to review and provide comment. If anyone so requests a public hearing within 15 days of
publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as
practicable to the location of the source. Any comments received during the public comment period and
the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the
comments received.

DAQE-IN141260002-24
Page 5

SECTION I: GENERAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available to
the Director which may include, but is not limited to, monitoring results, opacity observations,
review of operating and maintenance procedures, and inspection of the source. All
maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories.
[R307-150]

I.8 The owner/operator shall submit documentation of the status of construction or modification to
the Director within 18 months from the date of this AO. This AO may become invalid if
construction is not commenced within 18 months from the date of this AO or if construction is
discontinued for 18 months or more. To ensure proper credit when notifying the Director, send
the documentation to the Director, attn.: NSR Section. [R307-401-18]

DAQE-IN141260002-24
Page 6

SECTION II: PERMITTED EQUIPMENT

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.

II.A THE APPROVED EQUIPMENT

II.A.1 AT&T Data Facility

II.A.2 Three (3) Emergency Generator Engines
Fuel: Diesel

One (1) 40 kW (54 horsepower (hp)) Generator Engine (New)
Manufactured: 1998
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

Two (2) 500 kW (671 hp) Generator Engines
Manufactured: Pre-2005
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

II.A.3 Three (3) Aboveground Fuel Storage Tanks
Content: Diesel

Tank 1: 8,000 gallons
Tank 2: 150 gallons
Tank 3: 150 gallons

SECTION II: SPECIAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site-Wide Requirements
II.B.1.a The owner/operator shall not allow visible emissions from any stationary point or fugitive
emission source to exceed 20% opacity. [R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]

II.B.2 Emergency Engine Requirements
II.B.2.a The owner/operator shall not operate each emergency generator engine on site for more than 100
hours per calendar year for maintenance checks and readiness testing. Each emergency generator
engine on site may be operated for up to 50 hours per calendrer year in non-emergency
situations. Any operation in non-emergency situations shall be counted as part of the 100 hours
per calendar year for maintenance and testing. There is no time limit on the use of the engines
during emergencies. [40 CFR 63 Subpart ZZZZ, R307-401-8]

DAQE-IN141260002-24
Page 7

II.B.2.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
documenting the operation of each emergency engine shall be kept in a log and shall include the
following:

A. The date the emergency engine was used.

B. The duration of operation in hours.

C. The reason for the emergency engine usage.

[40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.2.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.2.b The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as
fuel in each emergency engine. [R307-401-8]

II.B.2.b.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur
diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8]

II.B.2.b.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain
records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel
fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the
ULSD requirements. [R307-401-8]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Supersedes AO DAQE-AN0141260001-08 dated November 13, 2008
Is Derived From Notice of Intent dated February 7, 2024
Incorporates Additional Information dated February 26, 2024

DAQE-IN141260002-24
Page 8

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document:

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by Environmental Protection Agency to classify
sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98,
Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal Division of Air Quality use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i)
GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818-
12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DAQE-NN141260002-24

May 2, 2024

Box Elder News & Journal
Legal Advertising Dept
PO BOX 370
Brigham City, UT 84302-0370

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Box Elder News &
Journal (Account Number: LOC0403) on May 8, 2024.

Please mail the invoice and affidavit of publication to the Utah State Department of Environmental
Quality, Division of Air Quality, P.O. Box 144820, Salt Lake City, Utah 84114-4820. If you have any
questions, contact Jeree Greenwood, who may be reached at [phone].

Sincerely,

{{$s }}

Jeree Greenwood
Office Technician

Enclosure

cc: Bear River Association of Governments
cc: Box Elder County

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

DAQE-NN141260002-24
Page 2
NOTICE

A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah
Administrative Code (UAC), has been received for consideration by the Director:

Company Name: AT&T
Location: AT&T Communications of the Mountain States, Incorporated - Standby
Generators – 1760 North Highway 38, Brigham City, UT
Project Description: AT&T Communications of the Mountain States (AT&T) owns/operates a data
center in Brigham City, Box Elder County. The data center includes emergency
generators that are used for electricity production during periods when electric
power from public utilities is interrupted.

AT&T has requested a modification to Approval Order DAQE-AN0141260001-
08 for the following changes:

- Remove three (3) 15 kW, diesel-fired, emergency generators (listed as EGEN1-
3 under Condition 7.A of Approval Order DAQE-AN0141260001-08);
- Add one (1) 40 kW, diesel-fired, emergency generator; and
- Update the capacity of the diesel storage tank (listed as Tank 1 under Condition
7.A of Approval Order DAQE-AN0141260001-08) from 4,000 gallons to 8,000
gallons.

The completed engineering evaluation and air quality impact analysis showed the proposed project meets
the requirements of federal air quality regulations and the State air quality rules. The Director intends to
issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the
effect on local air quality and draft Approval Order are available for public inspection and comment at the
Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments
received by the Division at this same address on or before June 7, 2024 will be considered in making the
final decision on the approval/disapproval of the proposed project. Email comments will also be accepted
at [e-mail]. If anyone so requests to the Director in writing within 15 days of publication of this
notice, a hearing will be held in accordance with
R307-401-7, UAC.

Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or
argument during an adjudicatory proceeding that was raised during the public comment period and was
supported with sufficient information or documentation to enable the Director to fully consider the
substance and significance of the issue.

Date of Notice: May 8, 2024

{{#s=Sig_es_:signer1:signature}}

Box Elder News Journal
Publication Name:
Box Elder News Journal
Publication URL:
www.benewsjournal.com
Publication City and State:
Brigham City, UT
Publication County:
Box Elder
Notice Popular Keyword Category:
Notice Keywords:
at&t
Notice Authentication Number:
202405081002213672996
1761527914
Notice URL:
Back
Notice Publish Date:
Wednesday, May 08, 2024
Notice Content
NOTICE OF INTENT
A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been received
for consideration by the Director:
Company Name: AT&T
Location: AT&T Communications of the Mountain States, Incorporated - Standby Generators – 1760 North Highway 38, Brigham City, UT
Project Description:
AT&T Communications of the Mountain States (AT&T) owns/operates a data center in Brigham City, Box Elder County. The data center
includes emergency generators that are used for electricity production during periods when electric power from public utilities is interrupted.
AT&T has requested a modification to Approval Order DAQE-AN0141260001- 08 for the following changes:
- Remove three (3) 15 kW, diesel-fired, emergency generators (listed as EGEN1- 3 under Condition 7.A of Approval Order DAQE-
AN0141260001-08);
- Add one (1) 40 kW, diesel-fired, emergency generator; and
- Update the capacity of the diesel storage tank (listed as Tank 1 under Condition 7.A of Approval Order DAQE-AN0141260001-08) from
4,000 gallons to 8,000 gallons.
The completed engineering evaluation and air quality impact analysis showed the proposed project meets the requirements of federal air
quality regulations and the State air quality rules. The Director intends to issue an Approval Order pending a 30-day public comment period.
The project proposal, estimate of the effect on local air quality and draft Approval Order are available for public inspection and comment at
the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments received by the Division at this same
5/8/24, 9:02 AM utahlegals.com/(S(fujsu31vxigv3mjoft2wc421))/DetailsPrint.aspx?SID=fujsu31vxigv3mjoft2wc421&ID=184338
https://www.utahlegals.com/(S(fujsu31vxigv3mjoft2wc421))/DetailsPrint.aspx?SID=fujsu31vxigv3mjoft2wc421&ID=184338 1/2
address on or before June 7, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email
comments will also be accepted at [e-mail]. If anyone so requests to the Director in writing within 15 days of publication of this
notice, a hearing will be held in accordance with R307-401-7, UAC.
Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory
proceeding that was raised during the public comment period and was supported with sufficient information or documentation to enable the
Director to fully consider the substance and significance of the issue.
Back
5/8/24, 9:02 AM utahlegals.com/(S(fujsu31vxigv3mjoft2wc421))/DetailsPrint.aspx?SID=fujsu31vxigv3mjoft2wc421&ID=184338
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DAQE-

RN141260002
April 25, 2024

Travis Bawcum
AT&T
1311 S Akard St, 12th Floor
Dallas, TX 75202
[e-mail]

Dear Travis Bawcum,

Re: Engineer Review:
Minor Modification to Approval Order DAQE-AN0141260001-08 to Update Equipment
Project Number: N141260002

The DAQ requests a company representative review and sign the attached Engineer Review (ER). This
ER identifies all applicable elements of the New Source Review permitting program. AT&T should
complete this review within 10 business days of receipt.

AT&T should contact Christine Bodell at [phone] if there are questions or concerns with the
review of the draft permit conditions. Upon resolution of your concerns, please email Christine Bodell at
[e-mail] the signed cover letter. Upon receipt of the signed cover letter, the DAQ will prepare
an ITA for a 30-day public comment period. At the completion of the comment period, the DAQ will
address any comments and will prepare an Approval Order (AO) for signature by the DAQ Director.

If AT&T does not respond to this letter within 10 business days, the project will move forward without
source concurrence. If AT&T has concerns that cannot be resolved and the project becomes stagnant, the
DAQ Director may issue an Order prohibiting construction.

Approval Signature _____________________________________________________________
(Signature & Date)

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of
Environmental Quality

Kimberly D. Shelley Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird Director

State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION

Project Number N141260002
Owner Name AT&T
Mailing Address 1311 S Akard St, 12th Floor
Dallas, TX, 75202

Source Name AT&T Communications of the Mountain States, Inc- Standby
Generators
Source Location 1760 North Highway 38
Brigham City, UT 84302

UTM Projection 415,463 m Easting, 4,599,323 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 4813 (Telephone Communications, Except Radiotelephone)

Source Contact Travis Bawcum
Phone Number [phone]
Email [e-mail]

Billing Contact Travis Bawcum
Phone Number [phone]
Email [e-mail]

Project Engineer Christine Bodell, Engineer
Phone Number [phone]
Email [e-mail]

Notice of Intent (NOI) Submitted February 7, 2024
Date of Accepted Application March 1, 2024

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 2
SOURCE DESCRIPTION

General Description
AT&T Communications of the Mountain States (AT&T) owns/operates a data center in Brigham
City, Box Elder County. The data center includes emergency generators that are used for
electricity production during periods when electric power from public utilities is interrupted.

NSR Classification:
Minor Modification at Minor Source

Source Classification
Located in Salt Lake City UT PM2.5 NAA
Box Elder County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Proposal
Minor Modification to Approval Order DAQE-AN0141260001-08 to Update Equipment

Project Description
AT&T Communications of the Mountain States (AT&T) has requested a modification to AO
DAQE-AN0141260001-08 for the following changes:

- Remove three (3) 15 kW, diesel-fired, emergency generators (listed as EGEN1-3 under
Condition 7.A of AO DAQE-AN0141260001-08);
- Add one (1) 40 kW, diesel-fired, emergency generator; and
- Update the capacity of the diesel storage tank (listed as Tank 1 under Condition 7.A of AO
DAQE-AN0141260001-08) from 4,000 gallons to 8,000 gallons.

EMISSION IMPACT ANALYSIS
All criteria pollutant emissions are decreasing. All HAPs emissions are decreasing, except for toluene and
xylene. The toluene and xylene emission increases did not trigger the requirement for AT&T to conduct
dispersion modeling under Utah Administrative Code R307-410-5. Therefore, no modeling is required. [Last
updated February 26, 2024]

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 3
SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent -3 405.00
Carbon Monoxide -0.01 1.93
Nitrogen Oxides -0.05 8.46
Particulate Matter - PM10 -0.01 0.26
Particulate Matter - PM2.5 -0.01 0.26
Sulfur Dioxide -0.17 0.00
Volatile Organic Compounds 0 0.27

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Generic HAPs (CAS #GHAPS) 1 8
Change (TPY) Total (TPY)
Total HAPs 0 0.00

Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 4
Review of BACT for New/Modified Emission Units

1. BACT review regarding New 40 kW (54 hp) Emergency Engine
The proposed emergency engine will result in 0.42 tpy of NOx, 0.09 tpy of CO, 0.03 tpy each of
PM10, PM2.5, and VOCs, and <0.01 tpy each of SO2 and HAPs.

One way of reducing overall engine emissions is to install newer equipment that meets EPA's
tiered emission standards. 40 CFR 60 Subpart IIII requires owners and operators of older (pre-
2004) emergency diesel-fired ICE to purchase engines certified by the manufacturer to the
USEPA's nonroad engine Tier 1 emission standards. AT&T has elected to install a 1998-
manufactured Tier 1 engine. Tier 1 certification limits emissions for NOx.

The engine will not exceed 100 hours of operation per year for maintenance and testing purposes.
The potential to emits are based on 500 hours of emergency use per engine. Due to the inconsistent
and low volume of air pollutants emitted from the engine during testing and maintenance, the cost
to replace the 40 kW Tier 1 engine with a Tier 2 or Tier 3 engine is considered cost prohibitive.
For the same reason, additional add-on controls such as use of an SCR (selective catalytic
reduction) or DOC (diesel oxidation catalyst) system to control PM10, PM2.5, VOCs, and HAPs are
cost prohibitive.

Therefore, BACT to control emissions from the new emergency generator engine is maintaining a
Tier 1 certification on the engine, as well as operating and maintaining the engine in accordance
with manufacturer recommendations. BACT is also ensuring the engine does not exceed 100 hours
of operation per rolling 12-month period for maintenance checks and readiness testing.

Sulfur dioxide emissions occur from the reaction of various sulfur compounds in the diesel fuel.
Sulfur in diesel fuel oxidizes during combustion to SO2 and sulfur trioxide (SO3). In the presence
of water vapor, these hydrolyze to H2SO4. AT&T will use ultra-low sulfur diesel fuel containing no
more than 15 parts per million by weight of sulfur which is considered BACT. BACT is also
maintaining visible emissions at or below 20% opacity. [Last updated February 26, 2024]

2. BACT review regarding 8,000-gallon Diesel Fuel Storage Tank
AT&T is increasing the capacity of one (1) 4,000-gallon diesel fuel storage tank to 8,000 gallons.
The 8,000-gallon tank was incorrectly permitted in 2007 as a 4,000-gallon diesel tank. The 8,000-
gallon tank has been installed since 2007.

Emissions from storage tanks result from displacement of headspace vapor during filling
operations (working losses) and from diurnal temperature and heating variations (breathing losses).
Typically, filling losses constitute 80-90% of the total losses for fixed roof tanks. For the storage
tank, control technologies include a vapor recovery system, submerged filling, and flaring. Vapor
recovery systems typically control highly volatile substances with high VOC waste streams. The
storage tank operates at a very low vapor pressure, making this option technically infeasible. The
storage tank would need to be retrofitted to accommodate submerged filling to reduce working
losses. The VOC emissions from increasing the tank capacity by 4000 gallons will be <0.001 tpy,
making any retrofits or additional add-on controls cost prohibitive.

Therefore, BACT to control VOC emissions from the storage tank is best operating practices. [Last
updated April 25, 2024]

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 5
SECTION I: GENERAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available
to the Director which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-
401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-
150]

I.8 The owner/operator shall submit documentation of the status of construction or modification
to the Director within 18 months from the date of this AO. This AO may become invalid if
construction is not commenced within 18 months from the date of this AO or if construction is
discontinued for 18 months or more. To ensure proper credit when notifying the Director,
send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 6
II.A THE APPROVED EQUIPMENT

II.A.1 AT&T Data Facility

II.A.2
NEW
Three (3) Emergency Generator Engines
Fuel: Diesel

One (1) 40 kW (54 horsepower (hp)) Generator Engine (New)
Manufactured: 1998
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

Two (2) 500 kW (671 hp) Generator Engines
Manufactured: Pre-2005
NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

II.A.3
NEW
Three (3) Aboveground Fuel Storage Tanks
Content: Diesel

Tank 1: 8,000 gallons
Tank 2: 150 gallons
Tank 3: 150 gallons

SECTION II: SPECIAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

II.B REQUIREMENTS AND LIMITATIONS

II.B.1
NEW
Site-Wide Requirements
II.B.1.a
NEW
The owner/operator shall not allow visible emissions from any stationary point or fugitive
emission source to exceed 20% opacity. [R307-401-8]

II.B.1.a.1
NEW
Opacity observations of emissions from stationary sources shall be conducted in accordance
with 40 CFR 60, Method 9. [R307-401-8]

II.B.2
NEW
Emergency Engine Requirements
II.B.2.a
NEW
The owner/operator shall not operate each emergency generator engine on site for more than
100 hours per calendar year for maintenance checks and readiness testing. Each emergency
generator engine on site may be operated for up to 50 hours per calendrer year in non-
emergency situations. Any operation in non-emergency situations shall be counted as part of
the 100 hours per calendar year for maintenance and testing. There is no time limit on the use
of the engines during emergencies. [40 CFR 63 Subpart ZZZZ, R307-401-8]

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 7
II.B.2.a.1
NEW
To determine compliance with a rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the 20th day of each month using data from the previous 12 months.
Records documenting the operation of each emergency engine shall be kept in a log and shall
include the following:

A. The date the emergency engine was used

B. The duration of operation in hours

C. The reason for the emergency engine usage

[40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.2.a.2
NEW
To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.2.b
NEW
The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives)
as fuel in each emergency engine. [R307-401-8]

II.B.2.b.1
NEW
The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur
diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8]

II.B.2.b.2
NEW
To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall
maintain records of diesel fuel purchase invoices or obtain certification of sulfur content from
the diesel fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel
meets the ULSD requirements. [R307-401-8]

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 8
PERMIT HISTORY

When issued, the approval order shall supersede (if a modification) or will be based on the
following documents:

Supersedes DAQE-AN0141260001-08 dated November 13, 2008
Is Derived From Notice of Intent dated February 7, 2024
Incorporates Additional Information dated February 26, 2024

REVIEWER COMMENTS

1. Comment regarding Source Emissions Estimates and DAQ Acceptance:
AT&T is replacing three (3) 15 kW, diesel-fired engine generators with one (1) 40 kW, diesel-fired
engine generator. AT&T is increasing the capacity of the 4,000-gallon diesel fuel tank to 8,000
gallons. The changes result in a net decrease in all criteria pollutants. There will be a net decrease in
combined HAPs emissions. However, xylenes will increase by 0.15 lbs, annually. Therefore, this
project is classified as a modification. Total HAPs are 7.8 lbs per year (<0.01 tpy).

AT&T elected to use 500 hours per year of emergency operation when estimating emissions from
the emergency engines. It is DAQ practice to use 100 hours per year for emergency engines. When
using 100 hours per year, the facility qualifies to be regulated as an exempted small source under
UAC R307-401-9. However, AT&T has elected to keep its AO, per correspondence on February 14,
2024.

The source estimated the emissions using the following:

Engines
500 kW (671 hp) Emergency Diesel Generators - AP-42; Section 3.4 Large Stationary Diesel And
All Stationary Dual-fuel Engines ( >600 hp)
40 kW (54 hp) Emergency Diesel Generator - AP-42; Section 3.3 Gasoline And Diesel Industrial
Engines (<600 hp)
For a conservative estimate, the source elected to estimate emissions assuming 500 hours/year of
emergency use.

Diesel Storage Tanks:
The maximum annual throughput for the two (2) aboveground 150-gallon tanks is 31,500 gallons per
year (each) and the maximum annual throughput for the aboveground 8,000-gallon tank is 35,010
gallons per year. Emissions were estimated using EPA Tanks. [Last updated March 19, 2024]

2. Comment regarding Federal Subpart Applicability:
40 CFR 60 (NSPS) Subpart Kb (Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984)
applies to "...each storage vessel with a capacity greater than or equal to 75 cubic meters (19,800
gallons), that is used to store volatile organic liquids for which construction, reconstruction, or
modification is commenced after July 23, 1984." There are three (3) existing storage tanks on site,
each with a capacity of less than 16,800 gallons. Therefore, NSPS Subpart Kb does not apply
to this facility.

The provisions of NSPS Subpart IIII (Standards of Performance or Stationary Compression Ignition
Internal Combustion Engines) apply to owners and operators of stationary CI ICE that commence

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 9
construction after July 11, 2005, where the stationary CI ICE are manufactured after April 1, 2006.
AT&T submitted an NOI for the two (2) existing 500 kW emergency generators on March 28, 2008.
Therefore, the two (2) existing 500 kW emergency generators and the new 40 kW emergency
generator were all installed post-2005. NSPS Subpart IIII applies to each engine.

40 CFR 63 Subpart ZZZZ (National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines) is applicable to owners/operators of
stationary RICE at a major or area sources of HAP emissions. The facility includes three (3) diesel-
fired emergency engine generators. The provisions of MACT Subpart ZZZZ apply as the stationary
reciprocating internal combustion engine (RICE) is at an area source of HAP emissions. The engine
not designated as nonroad and not exempt are affected sources under this regulation. Therefore,
MACT Subpart ZZZZ applies to this facility. [Last updated February 26, 2024]

3. Comment regarding Title V Applicability:
Title V of the 1990 Clean Air Act (Title V) applies to the following:

1. Any major source
2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act,
Standards of Performance for New Stationary Sources;
3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous
Air Pollutants.
4. Any Title IV affected source.

This facility is not a Title IV source or a major source. The facility is not subject to 40 CFR 61
(NESHAP) regulations. It is subject to 40 CFR 60 (NSPS) Subparts A and IIII and to 40 CFR 63
(MACT) Subparts A and ZZZZ. NSPS Subpart IIII and MACT Subpart ZZZZ each except sources
from the obligation to obtain a Title V permit provided that the source is not required to obtain the
permit for any other reason. No such reasons exist for this source. Therefore, Title V does not apply
to the AT&T facility. [Last updated March 19, 2024]

Engineer Review N141260002: AT&T Communications of the Mountain States, Inc- Standby Generators
April 25, 2024
Page 10
ACRONYMS
The following lists commonly used acronyms and associated translations as they apply to this
document:
40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by EPA to classify sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal UDAQ use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)
GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/HR Pounds per hour
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

7,000 BTU/hp-hr
Equipment Details
Rating 60 hp = (44.8 kw)Table 3.3-1
Operational Hours 500 hours/year <600 hp
Sulfur Content 15 ppm or 0.0015%lb/hp-hr lb/hr Ton/year Check EF x S lb/hp-hr lb/hr Ton/year Check
Nox - Uncontrolled 0.031 1.86 0.47 Match 0.024 1.44 0.36
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Nox - Controlled 0.013 0.78 0.20
NOX 0.031 1.86 0.47 CO 6.68E-03 0.40 0.10 Match 5.50E-03 0.33 0.08
CO 6.68E-03 0.40 0.10 SO2 2.05E-03 0.12 0.03 8.09E-03 1.21E-05 0.00 0.00 Match Used>600 hp to allow for sulfur content of fuel
PM10 2.20E-03 0.13 0.03 PM10 2.20E-03 0.13 0.03 Match 0.0007 0.04 0.01 Table 3.3-1 does not allow for a sulfur content.
PM2.5 2.20E-03 0.13 0.03 CO2 1.15E+00 69 17 Match 1.16 70 17 To be more representatvie, Table 3.4-1 was used for all engine sizes.
VOC 2.51E-03 0.15 0.04 Aldehydes 4.63E-04 Not used, included in HAP below.SO2 1.21E-05 0.00 0.00 AP-42 Table 3.4-1 TOC 2.51E-03 0.15 0.04 7.05E-04 0.04 0.01 for engines >600 hp, TOC is 91% VOC & 9% methane
HAP 0.00 0.00 See Below VOC 2.51E-03 0.15 0.04 Match 91%6.42E-04 0.04 0.01
Methane Match 9%6.35E-05 0.00 0.00
Green House Gas Pollutant
Global
Warming
Potential
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Exhaust 2.47E-03CO2 (mass basis)1 1.15E+00 69 17 Evaporative 0.00
Methane (mass basis)25 0 0 Crankcase 4.41E-05CO2e17Refueling0.00
Hazardous Air Pollutant
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference HAP
Table 3.3-2
<600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Table 3.4-3
>600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Benzene 9.33E-04 3.92E-04 9.80E-05 Benzene 9.33E-04 6.53E-06 3.92E-04 9.80E-05 Match 7.76E-04 5.43E-06 3.26E-04 8.15E-05
Toluene 4.09E-04 1.72E-04 4.29E-05 Toluene 4.09E-04 2.86E-06 1.72E-04 4.29E-05 Match 2.81E-04 1.97E-06 1.18E-04 2.95E-05
Xylenes 2.85E-04 1.20E-04 2.99E-05 Xylenes 2.85E-04 2.00E-06 1.20E-04 2.99E-05 Match 1.93E-04 1.35E-06 8.11E-05 2.03E-05
1,3-Butadiene 3.91E-05 1.64E-05 4.11E-06 1,3-Butadiene 3.91E-05 2.74E-07 1.64E-05 4.11E-06 Match
Formaldehyde 1.18E-03 4.96E-04 1.24E-04 Formaldehyde 1.18E-03 8.26E-06 4.96E-04 1.24E-04 Match 7.89E-05 5.52E-07 3.31E-05 8.28E-06
Acetaldehyde 7.67E-04 3.22E-04 8.05E-05 Acetaldehyde 7.67E-04 5.37E-06 3.22E-04 8.05E-05 Match 2.52E-05 1.76E-07 1.06E-05 2.65E-06
Acrolein 9.25E-05 3.89E-05 9.71E-06 Acrolein 9.25E-05 6.48E-07 3.89E-05 9.71E-06 Match 7.88E-06 5.52E-08 3.31E-06 8.27E-07
Naphthalene 8.48E-05 3.56E-05 8.90E-06 Naphthalene 8.48E-05 5.94E-07 3.56E-05 8.90E-06 Match 1.30E-04 9.10E-07 5.46E-05 1.37E-05
Acenaphthylene 5.06E-06 2.13E-06 5.31E-07 Acenaphthylene 5.06E-06 3.54E-08 2.13E-06 5.31E-07 Match 9.23E-06 6.46E-08 3.88E-06 9.69E-07
Acenaphthene 1.42E-06 5.96E-07 1.49E-07 Acenaphthene 1.42E-06 9.94E-09 5.96E-07 1.49E-07 Match 4.68E-06 3.28E-08 1.97E-06 4.91E-07
Fluorene 2.92E-05 1.23E-05 3.07E-06 Fluorene 2.92E-05 2.04E-07 1.23E-05 3.07E-06 Match 1.28E-05 8.96E-08 5.38E-06 1.34E-06
Phenanthrene 2.94E-05 1.23E-05 3.09E-06 Phenanthrene 2.94E-05 2.06E-07 1.23E-05 3.09E-06 Match 4.08E-05 2.86E-07 1.71E-05 4.28E-06
Anthracene 1.87E-06 7.85E-07 1.96E-07 Anthracene 1.87E-06 1.31E-08 7.85E-07 1.96E-07 Match 1.23E-06 8.61E-09 5.17E-07 1.29E-07
Fluoranthene 7.61E-06 3.20E-06 7.99E-07 Fluoranthene 7.61E-06 5.33E-08 3.20E-06 7.99E-07 Match 4.03E-06 2.82E-08 1.69E-06 4.23E-07
Pyrene 4.78E-06 2.01E-06 5.02E-07 Pyrene 4.78E-06 3.35E-08 2.01E-06 5.02E-07 Match 3.71E-06 2.60E-08 1.56E-06 3.90E-07
Benz(a)anthracene 1.68E-06 7.06E-07 1.76E-07 Benz(a)anthracene 1.68E-06 1.18E-08 7.06E-07 1.76E-07 Match 6.22E-07 4.35E-09 2.61E-07 6.53E-08
Chrysene 3.53E-07 1.48E-07 3.71E-08 Chrysene 3.53E-07 2.47E-09 1.48E-07 3.71E-08 Match 1.53E-06 1.07E-08 6.43E-07 1.61E-07
Benzo(b)fluoranthene 9.91E-08 4.16E-08 1.04E-08 Benzo(b)fluoranthene 9.91E-08 6.94E-10 4.16E-08 1.04E-08 Match 1.11E-06 7.77E-09 4.66E-07 1.17E-07
Benzo(k)fluoranthene 1.55E-07 6.51E-08 1.63E-08 Benzo(k)fluoranthene 1.55E-07 1.09E-09 6.51E-08 1.63E-08 Match 2.18E-07 1.53E-09 9.16E-08 2.29E-08
Benzo(a)pyrene 1.88E-07 7.90E-08 1.97E-08 Benzo(a)pyrene 1.88E-07 1.32E-09 7.90E-08 1.97E-08 Match 2.57E-07 1.80E-09 1.08E-07 2.70E-08
Indeno(1,2,3-cd)pyrene 3.75E-07 1.58E-07 3.94E-08 Indeno(1,2,3-cd)pyrene 3.75E-07 2.63E-09 1.58E-07 3.94E-08 Match 4.14E-07 2.90E-09 1.74E-07 4.35E-08
Dibenz(a,h)anthracene 5.83E-07 2.45E-07 6.12E-08 Dibenz(a,h)anthracene 5.83E-07 4.08E-09 2.45E-07 6.12E-08 Match 3.46E-07 2.42E-09 1.45E-07 3.63E-08
Benzo(g,h,l)perylene 4.89E-07 2.05E-07 5.13E-08 Benzo(g,h,l)perylene 4.89E-07 3.42E-09 2.05E-07 5.13E-08 Match 5.56E-07 3.89E-09 2.34E-07 5.84E-08
AP-42 Table 3.3-1
& Table 3.4-1
Emission Factor
(lb/MMBtu)
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
(1,3-Butadiene will
not popluate if the
engine size is greater
than 600 hp. AP-42
does not list 1,3-
Butadiene for
engines greater than
600 hp.)
Diesel-Fired Engines
Emergency Engines should
equal 100 hours of
operation per year
Table 3.4-1
>600 hp
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
Page 1 of Version 1.1 February 21, 2019
7,000 BTU/hp-hr
Equipment Details
Rating 1,342 hp = (1001.5 kw)Table 3.3-1
Operational Hours 500 hours/year <600 hp
Sulfur Content 15 ppm or 0.0015%lb/hp-hr lb/hr Ton/year Check EF x S lb/hp-hr lb/hr Ton/year Check
Nox - Uncontrolled 0.031 41.60 10.40 0.024 32.21 8.05 Match
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Nox - Controlled 0.013 17.45 4.36
NOX 0.024 32.21 8.05 CO 6.68E-03 8.96 2.24 5.50E-03 7.38 1.85 Match
CO 5.50E-03 7.38 1.85 SO2 2.05E-03 2.75 0.69 8.09E-03 1.21E-05 0.02 0.00 Match Used>600 hp to allow for sulfur content of fuel
PM10 7.00E-04 0.94 0.23 PM10 2.20E-03 2.95 0.74 0.0007 0.94 0.23 Match Table 3.3-1 does not allow for a sulfur content.
PM2.5 7.00E-04 0.94 0.23 CO2 1.15E+00 1,543 386 1.16 1,557 389 Match To be more representatvie, Table 3.4-1 was used for all engine sizes.
VOC 6.42E-04 0.86 0.22 Aldehydes 4.63E-04 Not used, included in HAP below.SO2 1.21E-05 0.02 0.00 AP-42 Table 3.4-1 TOC 2.51E-03 3.37 0.84 7.05E-04 0.95 0.24 for engines >600 hp, TOC is 91% VOC & 9% methane
HAP 0.01 0.00 See Below VOC 2.51E-03 3.37 0.84 91%6.42E-04 0.86 0.22 Match
Methane 9%6.35E-05 0.09 0.02 Match
Green House Gas Pollutant
Global
Warming
Potential
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Exhaust 2.47E-03CO2 (mass basis)1 1.16 1,557 389 Evaporative 0.00
Methane (mass basis)25 6.35E-05 0 0 Crankcase 4.41E-05CO2e390Refueling0.00
Hazardous Air Pollutant
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference HAP
Table 3.3-2
<600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Table 3.4-3
>600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Benzene 7.76E-04 7.29E-03 1.82E-03 Benzene 9.33E-04 6.53E-06 8.76E-03 2.19E-03 7.76E-04 5.43E-06 7.29E-03 1.82E-03 Match
Toluene 2.81E-04 2.64E-03 6.60E-04 Toluene 4.09E-04 2.86E-06 3.84E-03 9.61E-04 2.81E-04 1.97E-06 2.64E-03 6.60E-04 Match
Xylenes 1.93E-04 1.81E-03 4.53E-04 Xylenes 2.85E-04 2.00E-06 2.68E-03 6.69E-04 1.93E-04 1.35E-06 1.81E-03 4.53E-04 Match
1,3-Butadiene 3.91E-05 2.74E-07 3.67E-04 9.18E-05 Match
Formaldehyde 7.89E-05 7.41E-04 1.85E-04 Formaldehyde 1.18E-03 8.26E-06 1.11E-02 2.77E-03 7.89E-05 5.52E-07 7.41E-04 1.85E-04 Match
Acetaldehyde 2.52E-05 2.37E-04 5.92E-05 Acetaldehyde 7.67E-04 5.37E-06 7.21E-03 1.80E-03 2.52E-05 1.76E-07 2.37E-04 5.92E-05 Match
Acrolein 7.88E-06 7.40E-05 1.85E-05 Acrolein 9.25E-05 6.48E-07 8.69E-04 2.17E-04 7.88E-06 5.52E-08 7.40E-05 1.85E-05 Match
Naphthalene 1.30E-04 1.22E-03 3.05E-04 Naphthalene 8.48E-05 5.94E-07 7.97E-04 1.99E-04 1.30E-04 9.10E-07 1.22E-03 3.05E-04 Match
Acenaphthylene 9.23E-06 8.67E-05 2.17E-05 Acenaphthylene 5.06E-06 3.54E-08 4.75E-05 1.19E-05 9.23E-06 6.46E-08 8.67E-05 2.17E-05 Match
Acenaphthene 4.68E-06 4.40E-05 1.10E-05 Acenaphthene 1.42E-06 9.94E-09 1.33E-05 3.33E-06 4.68E-06 3.28E-08 4.40E-05 1.10E-05 Match
Fluorene 1.28E-05 1.20E-04 3.01E-05 Fluorene 2.92E-05 2.04E-07 2.74E-04 6.86E-05 1.28E-05 8.96E-08 1.20E-04 3.01E-05 Match
Phenanthrene 4.08E-05 3.83E-04 9.58E-05 Phenanthrene 2.94E-05 2.06E-07 2.76E-04 6.90E-05 4.08E-05 2.86E-07 3.83E-04 9.58E-05 Match
Anthracene 1.23E-06 1.16E-05 2.89E-06 Anthracene 1.87E-06 1.31E-08 1.76E-05 4.39E-06 1.23E-06 8.61E-09 1.16E-05 2.89E-06 Match
Fluoranthene 4.03E-06 3.79E-05 9.46E-06 Fluoranthene 7.61E-06 5.33E-08 7.15E-05 1.79E-05 4.03E-06 2.82E-08 3.79E-05 9.46E-06 Match
Pyrene 3.71E-06 3.49E-05 8.71E-06 Pyrene 4.78E-06 3.35E-08 4.49E-05 1.12E-05 3.71E-06 2.60E-08 3.49E-05 8.71E-06 Match
Benz(a)anthracene 6.22E-07 5.84E-06 1.46E-06 Benz(a)anthracene 1.68E-06 1.18E-08 1.58E-05 3.95E-06 6.22E-07 4.35E-09 5.84E-06 1.46E-06 Match
Chrysene 1.53E-06 1.44E-05 3.59E-06 Chrysene 3.53E-07 2.47E-09 3.32E-06 8.29E-07 1.53E-06 1.07E-08 1.44E-05 3.59E-06 Match
Benzo(b)fluoranthene 1.11E-06 1.04E-05 2.61E-06 Benzo(b)fluoranthene 9.91E-08 6.94E-10 9.31E-07 2.33E-07 1.11E-06 7.77E-09 1.04E-05 2.61E-06 Match
Benzo(k)fluoranthene 2.18E-07 2.05E-06 5.12E-07 Benzo(k)fluoranthene 1.55E-07 1.09E-09 1.46E-06 3.64E-07 2.18E-07 1.53E-09 2.05E-06 5.12E-07 Match
Benzo(a)pyrene 2.57E-07 2.41E-06 6.04E-07 Benzo(a)pyrene 1.88E-07 1.32E-09 1.77E-06 4.42E-07 2.57E-07 1.80E-09 2.41E-06 6.04E-07 Match
Indeno(1,2,3-cd)pyrene 4.14E-07 3.89E-06 9.72E-07 Indeno(1,2,3-cd)pyrene 3.75E-07 2.63E-09 3.52E-06 8.81E-07 4.14E-07 2.90E-09 3.89E-06 9.72E-07 Match
Dibenz(a,h)anthracene 3.46E-07 3.25E-06 8.13E-07 Dibenz(a,h)anthracene 5.83E-07 4.08E-09 5.48E-06 1.37E-06 3.46E-07 2.42E-09 3.25E-06 8.13E-07 Match
Benzo(g,h,l)perylene 5.56E-07 5.22E-06 1.31E-06 Benzo(g,h,l)perylene 4.89E-07 3.42E-09 4.59E-06 1.15E-06 5.56E-07 3.89E-09 5.22E-06 1.31E-06 Match
AP-42 Table 3.3-1
& Table 3.4-1
Emission Factor
(lb/MMBtu)
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
(1,3-Butadiene will
not popluate if the
engine size is greater
than 600 hp. AP-42
does not list 1,3-
Butadiene for
engines greater than
600 hp.)
Diesel-Fired Engines
Emergency Engines should
equal 100 hours of
operation per year
Table 3.4-1
>600 hp
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
Page 2 of Version 1.1 February 21, 2019
7,000 BTU/hp-hr
Equipment Details
Rating 54 hp = (40.3 kw)Table 3.3-1
Operational Hours 500 hours/year <600 hp
Sulfur Content 15 ppm or 0.0015%lb/hp-hr lb/hr Ton/year Check EF x S lb/hp-hr lb/hr Ton/year Check
Nox - Uncontrolled 0.031 1.67 0.42 Match 0.024 1.30 0.32
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Nox - Controlled 0.013 0.70 0.18
NOX 0.031 1.67 0.42 CO 6.68E-03 0.36 0.09 Match 5.50E-03 0.30 0.07
CO 6.68E-03 0.36 0.09 SO2 2.05E-03 0.11 0.03 8.09E-03 1.21E-05 0.00 0.00 Match Used>600 hp to allow for sulfur content of fuel
PM10 2.20E-03 0.12 0.03 PM10 2.20E-03 0.12 0.03 Match 0.0007 0.04 0.01 Table 3.3-1 does not allow for a sulfur content.
PM2.5 2.20E-03 0.12 0.03 CO2 1.15E+00 62 16 Match 1.16 63 16 To be more representatvie, Table 3.4-1 was used for all engine sizes.
VOC 2.51E-03 0.14 0.03 Aldehydes 4.63E-04 Not used, included in HAP below.SO2 1.21E-05 0.00 0.00 AP-42 Table 3.4-1 TOC 2.51E-03 0.14 0.03 7.05E-04 0.04 0.01 for engines >600 hp, TOC is 91% VOC & 9% methane
HAP 0.00 0.00 See Below VOC 2.51E-03 0.14 0.03 Match 91%6.42E-04 0.03 0.01
Methane Match 9%6.35E-05 0.00 0.00
Green House Gas Pollutant
Global
Warming
Potential
Emission
Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference Exhaust 2.47E-03CO2 (mass basis)1 1.15E+00 62 16 Evaporative 0.00
Methane (mass basis)25 0 0 Crankcase 4.41E-05CO2e16Refueling0.00
Hazardous Air Pollutant
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year)Reference HAP
Table 3.3-2
<600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Table 3.4-3
>600 hp
(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Benzene 9.33E-04 3.53E-04 8.82E-05 Benzene 9.33E-04 6.53E-06 3.53E-04 8.82E-05 Match 7.76E-04 5.43E-06 2.93E-04 7.33E-05
Toluene 4.09E-04 1.55E-04 3.87E-05 Toluene 4.09E-04 2.86E-06 1.55E-04 3.87E-05 Match 2.81E-04 1.97E-06 1.06E-04 2.66E-05
Xylenes 2.85E-04 1.08E-04 2.69E-05 Xylenes 2.85E-04 2.00E-06 1.08E-04 2.69E-05 Match 1.93E-04 1.35E-06 7.30E-05 1.82E-05
1,3-Butadiene 3.91E-05 1.48E-05 3.69E-06 1,3-Butadiene 3.91E-05 2.74E-07 1.48E-05 3.69E-06 Match
Formaldehyde 1.18E-03 4.46E-04 1.12E-04 Formaldehyde 1.18E-03 8.26E-06 4.46E-04 1.12E-04 Match 7.89E-05 5.52E-07 2.98E-05 7.46E-06
Acetaldehyde 7.67E-04 2.90E-04 7.25E-05 Acetaldehyde 7.67E-04 5.37E-06 2.90E-04 7.25E-05 Match 2.52E-05 1.76E-07 9.53E-06 2.38E-06
Acrolein 9.25E-05 3.50E-05 8.74E-06 Acrolein 9.25E-05 6.48E-07 3.50E-05 8.74E-06 Match 7.88E-06 5.52E-08 2.98E-06 7.45E-07
Naphthalene 8.48E-05 3.21E-05 8.01E-06 Naphthalene 8.48E-05 5.94E-07 3.21E-05 8.01E-06 Match 1.30E-04 9.10E-07 4.91E-05 1.23E-05
Acenaphthylene 5.06E-06 1.91E-06 4.78E-07 Acenaphthylene 5.06E-06 3.54E-08 1.91E-06 4.78E-07 Match 9.23E-06 6.46E-08 3.49E-06 8.72E-07
Acenaphthene 1.42E-06 5.37E-07 1.34E-07 Acenaphthene 1.42E-06 9.94E-09 5.37E-07 1.34E-07 Match 4.68E-06 3.28E-08 1.77E-06 4.42E-07
Fluorene 2.92E-05 1.10E-05 2.76E-06 Fluorene 2.92E-05 2.04E-07 1.10E-05 2.76E-06 Match 1.28E-05 8.96E-08 4.84E-06 1.21E-06
Phenanthrene 2.94E-05 1.11E-05 2.78E-06 Phenanthrene 2.94E-05 2.06E-07 1.11E-05 2.78E-06 Match 4.08E-05 2.86E-07 1.54E-05 3.86E-06
Anthracene 1.87E-06 7.07E-07 1.77E-07 Anthracene 1.87E-06 1.31E-08 7.07E-07 1.77E-07 Match 1.23E-06 8.61E-09 4.65E-07 1.16E-07
Fluoranthene 7.61E-06 2.88E-06 7.19E-07 Fluoranthene 7.61E-06 5.33E-08 2.88E-06 7.19E-07 Match 4.03E-06 2.82E-08 1.52E-06 3.81E-07
Pyrene 4.78E-06 1.81E-06 4.52E-07 Pyrene 4.78E-06 3.35E-08 1.81E-06 4.52E-07 Match 3.71E-06 2.60E-08 1.40E-06 3.51E-07
Benz(a)anthracene 1.68E-06 6.35E-07 1.59E-07 Benz(a)anthracene 1.68E-06 1.18E-08 6.35E-07 1.59E-07 Match 6.22E-07 4.35E-09 2.35E-07 5.88E-08
Chrysene 3.53E-07 1.33E-07 3.34E-08 Chrysene 3.53E-07 2.47E-09 1.33E-07 3.34E-08 Match 1.53E-06 1.07E-08 5.78E-07 1.45E-07
Benzo(b)fluoranthene 9.91E-08 3.75E-08 9.36E-09 Benzo(b)fluoranthene 9.91E-08 6.94E-10 3.75E-08 9.36E-09 Match 1.11E-06 7.77E-09 4.20E-07 1.05E-07
Benzo(k)fluoranthene 1.55E-07 5.86E-08 1.46E-08 Benzo(k)fluoranthene 1.55E-07 1.09E-09 5.86E-08 1.46E-08 Match 2.18E-07 1.53E-09 8.24E-08 2.06E-08
Benzo(a)pyrene 1.88E-07 7.11E-08 1.78E-08 Benzo(a)pyrene 1.88E-07 1.32E-09 7.11E-08 1.78E-08 Match 2.57E-07 1.80E-09 9.71E-08 2.43E-08
Indeno(1,2,3-cd)pyrene 3.75E-07 1.42E-07 3.54E-08 Indeno(1,2,3-cd)pyrene 3.75E-07 2.63E-09 1.42E-07 3.54E-08 Match 4.14E-07 2.90E-09 1.56E-07 3.91E-08
Dibenz(a,h)anthracene 5.83E-07 2.20E-07 5.51E-08 Dibenz(a,h)anthracene 5.83E-07 4.08E-09 2.20E-07 5.51E-08 Match 3.46E-07 2.42E-09 1.31E-07 3.27E-08
Benzo(g,h,l)perylene 4.89E-07 1.85E-07 4.62E-08 Benzo(g,h,l)perylene 4.89E-07 3.42E-09 1.85E-07 4.62E-08 Match 5.56E-07 3.89E-09 2.10E-07 5.25E-08
AP-42 Table 3.3-1
& Table 3.4-1
Emission Factor
(lb/MMBtu)
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
(1,3-Butadiene will
not popluate if the
engine size is greater
than 600 hp. AP-42
does not list 1,3-
Butadiene for
engines greater than
600 hp.)
Diesel-Fired Engines
Emergency Engines should
equal 100 hours of
operation per year
Table 3.4-1
>600 hp
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
Page 3 of Version 1.1 February 21, 2019
Criteria Current 3-15kW 2-500kW 1-40 kW Tank New PTE NOI DifferenceNOX8.51 0.47 8.05 0.42 8.47 8.46 -0.05
CO 1.94 0.10 1.85 0.09 1.94 1.93 -0.01 Source emission estimates are aPM100.27 0.03 0.23 0.03 0.26 0.26 -0.01
PM2.5 0.27 0.03 0.23 0.03 0.26 0.26 -0.01
VOC 0.27 0.04 0.22 0.03 0.00111 0.25 0.27 0.00SO20.17 0.00 0.00 0.00 0.00 0 -0.17
HAP 0.0039 0.00 0.00 0.00 0.00 0.004 0.00
CO2e 407 17 390 16 405.24

AT&T / NOI Application
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UTAH DIVISION OF AIR QUALITY – NOTICE
OF INTENT
AT&T Communications of the Mountain States –
Brigham City, Utah

Prepared by:
TRINITY CONSULTANTS
4525 Wasatch Boulevard
Suite 200
Salt Lake City, Utah 84104
[phone]

January 2024

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TABLE OF CONTENTS
1. EXECUTIVE SUMMARY 1-1
2. GENERAL INFORMATION 2-1
2.1 Source Identification Summary ........................................................................... 2-1
2.2 Area Designation ................................................................................................. 2-1
2.3 Source Size Determination .................................................................................. 2-1
2.4 Notice of Intent Forms ........................................................................................ 2-2
2.5 Notice of Intent Fees ........................................................................................... 2-2
3. DESCRIPTION OF PROJECT 3-1
3.1 Description of Project .......................................................................................... 3-1
3.2 Site Plan .............................................................................................................. 3-1
4. EMISSION RELATED INFORMATION 4-1
4.1 Diesel-Fired Emergency Generators .................................................................... 4-1
4.2 Organic Liquid Storage Tank ............................................................................... 4-2
5. BEST AVAILABLE CONTROL TECHNOLOGY (BACT) ANALYSIS 5-3
5.1 Emergency Generator .......................................................................................... 5-3
5.1.1 Diesel-Fired Engine Step 1- Identify Potential Control Technologies .............................. 5-3
5.1.2 Diesel-Fired Engines Step 2 – Eliminate Technically Infeasible Options ......................... 5-4
5.1.3 Diesel-Fired Engines Step 3 – Ranking of Remaining Control Technologies by Control
Effectiveness ..................................................................................................................... 5-5
5.1.4 Diesel-Fired Engine Step 4 – Evaluate Most Effective Controls and Document Results .... 5-6
5.1.5 Diesel-Fired Engine Step 5 – Select BACT .................................................................. 5-6
5.2 Organic Liquid Storage Tank ............................................................................... 5-6
5.2.1 Organic Liquid Storage Tank Step 1- Identify Potential Control Technologies ................. 5-6
5.2.2 Organic Liquid Storage Tank Steps 2 - 4 .................................................................... 5-7
5.2.3 Diesel-Fired Engine Step 5 ....................................................................................... 5-7
6. EMISSION IMPACT ANALYSIS 6-1
7. EMISSION IMPACT ANALYSIS 7-1
7.1 Offset Applicability .............................................................................................. 7-1
7.1.1 PM2.5 Offsets........................................................................................................... 7-1
8. REGULATORY ANALYSIS 8-1
8.1 UDAQ Air Quality Rules ....................................................................................... 8-1
8.1.1 UAC R307-101 General Requirements: ...................................................................... 8-4
8.1.2 UAC R307-107 General Requirements: Breakdowns .................................................... 8-5
8.1.3 UAC R307-201 Emission Standards: General Emission Standards ................................. 8-5
8.1.4 UAC R307-203 Emission Standards: Sulfur Content of Fuels ........................................ 8-5
8.1.5 UAC R307-309 Nonattainment and Maintenance Areas for PM10 and PM2.5: Fugitive
Emissions and Fugitive Dust ............................................................................................... 8-5
8.1.6 UAC R307-401-8 Permits: Permit New and Modified Sources – Approval Order: ............. 8-5
8.1.7 UAC R307-414 Permits: Fees for Approval Orders: ..................................................... 8-6
8.2 Federal Rules: National Emission Standards for Hazardous Air Pollutants .......... 8-6
8.2.1 Subpart A – General Provisions ................................................................................. 8-6

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8.2.2 Subpart ZZZZ – Stationary Reciprocating Internal Combustion Engines ......................... 8-7
8.3 Federal Rules: New Source Performance Standards ............................................ 8-7
8.3.1 Subpart A-General Provisions ................................................................................... 8-7
8.3.2 NSPS Subpart IIII – Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines .......................................................................................................... 8-7
APPENDIX A. FORMS A-1
APPENDIX B. EMISSIONS CALCULATION B-1
APPENDIX C. SUPPORTING BACT INFORMATION C-1

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1. EXECUTIVE SUMMARY
AT&T Communications of the Mountain States (AT&T) operates a data center (the Facility) located at 1760
North Highway 38 in Brigham City, Box Elder County, Utah, with air emissions primarily due to the operation
of emergency generators. Box Elder County is an attainment area of the National Ambient Air Quality
Standards (NAAQS) for all pollutants with exception to PM2.5 for which it is classified as serious nonattainment.
The Facility currently operates under Utah Approval Order (AO) DAQE-AN0141260001-08.

AT&T is proposing to make the following changes to the Facility:
► Remove three (3) 15 kW emergency generators (ID: EGEN:1-3);
► Add one (1) 40 kW emergency generator; and
► Update the representation of the diesel storage tank (ID: TANK 1) from 4,000 gallons to 8,000 gallons.

The facilities will be subject to New Source Performance Standards (NSPS) 40 Code of Federal Regulations
(CFR) 60 Subpart A (General Provisions), NSPS 40 CFR 60 Subpart IIII (Standards of Performance for
Stationary Compression Ignition Internal Combustion Engines), National Emissions Standards for Hazardous
Air Pollutants (NESHAP) 63 Subpart A (General Provisions), NESHAP 63 Subpart ZZZZ (Stationary
Reciprocating Internal Combustion Engines).

This NOI air quality application is being submitted in accordance with the Utah Division of Air Quality (UDAQ)
rules, Utah Administrative Code (UAC) R307-401, and includes all supporting documentation in order to modify
DAQE-AN0141260001-08 and obtain authorization for the changes specified above. Appendix B summarizes
the emissions resulting from the Facility after the proposed changes. This NOI includes the following:

► NOI Air Permit Application Forms and Fees;
► Process Description;
► Potential to Emit (PTE) Calculations;
► Best Available Control Technology (BACT) Analysis; and,
► Applicable Requirements.

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2. GENERAL INFORMATION
The following section contains the information requested under the “Source Identification Information” section
of UDAQ’s Form 1 Notice of Intent (NOI) Application Checklist.
2.1 Source Identification Summary
Institution Name: AT&T Communications of the Mountain States, Inc.
Address: 1760 North Highway 38, Brigham City, UT 84302-3711
County: Box Elder County
UTM Coordinates: 4,599,323 meters N, 415,463 meters E, Zone 12
Primary SIC Code: 4813 – Telephone Communications, except Radiotelephone
Source Size Determination: Nonattainment area PM2.5 ► Current AO: AN103540030-22
All correspondence regarding this submission should be addressed to:

Julianne Barnum
AT&T Communications of the Mountain States, Inc.
Area Manager EHS
1311 S. Akard St., 12th Floor
Dallas, TX 75202
Phone: [phone]
Email: [e-mail]
2.2 Area Designation
AT&T is located within an area of Box Elder County that is classified as in attainment for all pollutants with
exception to PM2.5 for which it is classified as serious nonattainment area of the National Ambient Air Quality
Standards (NAAQS).
2.3 Source Size Determination
As presented in Appendix B, site-wide emissions at the Facility are less than the Major Source Thresholds
(MST) for all criteria pollutants. Therefore, the Facility is classified as a minor source.

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2.4 Notice of Intent Forms
The following UDAQ forms have been included with this NOI air permit application:
• Form 1 – Notice of Intent (NOI) Application Checklist;
• Form 2 – Company Information/Notice of Intent (NOI);
• Form 4 – Project Information;
• Form 5 – Emissions Information Criteria/GHGs/HAPs;
• Form 17 – Diesel Powered Standby Generator; and
• Form 20 – Organic Liquid Storage Tank.
2.5 Notice of Intent Fees
AT&T will use the UDAQ’s Payment Portal to prepay the following UDAQ NOI air permit application fees
associated with this submittal:

“Application Filing Fee” for the “New Minor Source or Minor Modification at Minor or Major Source” category
= $500; and

“Application Review Fee” for the “New Minor Source or Minor Modification at Minor or Major Source” category
in maintenance or non-attainment areas = $2,300.

Total UDAQ fees = $2,800.

AT&T understands that the total permit review fee is based on the total actual time spent by UDAQ staff
processing this NOI air permit application. Upon issuance of the AO, if the total review time is more than 20
standard hours, UDAQ will invoice AT&T at $115 per hour for the additional time above 20 standard hours.

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3. DESCRIPTION OF PROJECT
3.1 Description of Project
AT&T currently operates emergency generators at the data center for electricity production only during periods
when electric power from public utilities is interrupted, or for regular maintenance of the generators. In June
2016, AT&T replaced three (3) existing 15 kW generators with one (1) 40kW generator. AT&T is now
requesting that this change be reflected in its AO. Associated with the change in generators, AT&T is also
updating the volume of Diesel Tank 1 to 8,000 gallons which was previously permitted at 4,000 gallons. The
changes are summarized below:

► Remove three (3) 15 kW emergency generators (ID: EGEN:1-3);
► Add one (1) 40 kW emergency generator; and
► Update the representation of the diesel storage tank (ID: TANK 1) from 4,000 gallons to 8,000 gallons.
3.2 Site Plan
Figure 3-1 shows the location of the Facility.
Figure 3-1. Location of AT&T Data Center

AT&T Data Center
1760 North Highway 38,
Brigham City, UT 84302

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4. EMISSION RELATED INFORMATION
This section details the methodology used to calculate controlled and uncontrolled emissions for criteria
pollutants and Hazardous Air Pollutants (HAPs) associated with each new unit and its associated fugitives as
regulated by R307-401-5(2)(b). Detailed emission calculation tables are included in Appendix B. Additionally,
a comparison to major source thresholds is conducted.
4.1 Diesel-Fired Emergency Generators
Emission calculations were performed for both the emergency generators to be removed and the proposed
emergency generator with a proposed cap of 100 hours of operation per year per generator, inclusive of
testing and maintenance. Calculations for each of the criteria pollutants are based on the annual hours of
operation at the maximum power output of the engine. Emission factors (EF) for diesel-fired operation were
obtained from the Environmental Protection Agency (EPA) AP 42, Volume I, Fifth Edition, Table 3.3-1.

The following calculations were carried out for each generator for NOX, CO, PM10, PM2.5, SO2, and Volatile
Organic Compounds (VOCs).
Annual Emission Rate (tpy)=Emission Factor �lbshp-hr�× Power Output [hp]× Hours of Operation �hrsyr�× Conversion �1 ton2000 lbs�

The proposed emergency engine will be using ultra-low sulfur diesel (ULSD) fuel. The emission factor for SO2
is based on a fuel sulfur content of 0.0015% for ultra-low sulfur diesel fuel, as defined under 40 CFR 80,
Subpart I, Section 80.510(c)(1). The SO2 emission factor from AP 42, Section 3.3 Table 3.3-1 is used in the
emission calculations and accounts for the fuel sulfur content. SO2 hourly emissions are calculated using the
following equation.
SO2 Hourly Emission Rate �lbshr�=Emission Factor �lbshp-hr�× Power Output [hp]
SO2 Annual Emission Rate (tpy)=Hourly Emissions �lbshr�× Hours of Operation �hrsyr�
× Conversion �1 ton2000 lbs�

HAP emissions were determined using the maximum heat input and annual hours of operation. Emission
factors for HAPs are obtained from AP-42, Section 3.3, Table 3.3-2.
HAP Annual Emission Rate (tpy)=Emission Factor �lbsMMBtu�× Heat Input �MMBtuhr�×Hours of Operation �hrsyr�× �tons2000 lb�

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4.2 Organic Liquid Storage Tank
Emission calculations were performed to quantify the emissions implications of increasing the represented
volume of the diesel storage tank from 4,000 gal to 8,000 gal. Tank HAP and VOC emissions were calculated
based on an unchanged maximum annual throughput of 31,500 gallons per year using the EPA approved
TankESP software which is based on AP-42 Section 7.1, Liquid Storage Tanks (June 2020). See the emission
calculations and the TankESP output in Appendix B for further details.

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5. BEST AVAILABLE CONTROL TECHNOLOGY (BACT) ANALYSIS
In the State of Utah, under R307-401-5(2)(d), Notice of Intent, every facility, operation, or process that
proposes any activity that would emit an air contaminant into the air, must consider BACT for a proposed new
source or modification.1 The below BACT analysis only addresses units which will be modified, installed, or
otherwise addressed in this NOI.
5.1 Emergency Generator
5.1.1 Diesel-Fired Engine Step 1- Identify Potential Control Technologies
The least stringent emission rate allowable for BACT is any applicable limit under either New Source
Performance Standards (NSPS – Part 60,) or National Emission Standards for Hazardous Air Pollutants
(NESHAP – Part 63). Emission limits for diesel-fired engines are limited by EPA’s Tier program established in
40 CFR 1039, and are referenced by NSPS Subpart IIII, Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines.2 Under these regulations EPA requires manufacturers to reduce the
emissions from engines produced after certain dates in a tiered fashion, based on the size and model year.
In general, the higher the tier rating, the lower the emissions produced.

The proposed unit is 40kW and meets Tier 1 emission standards for all pollutants. It is the manufacturer’s
responsibility to ensure that these units meet the established emission limitations or Tier rating. In order to
ensure these emission limitations are met manufacturers often incorporate design elements, such as
turbochargers, aftercoolers, positive crankcase ventilation, and high-pressure fuel injection. The incorporation
of these design elements allows the units to meet minimum BACT standards and are therefore not further
considered in this analysis.

In order to identify additional control technologies applied to emergency use engines the following sources
were reviewed:

• EPA’s RBLC Database for Diesel Generators (process type 17.210 Small Internal Combustion Engines
[<500 Hp] burning Fuel Oil);3
• EPA’s Air Pollution Technology Fact Sheets;
• SCAQMD Example Permits;
• TCEQ’s BACT combustion workbook; and
• BAAQMD Nonroad BACT Assessments.

The following control methods have been identified as potentially feasible for control of emissions from
emergency generator engines:

• Limited Hours of Operation;
• Good Combustion Practices (GCP);
• Exhaust Gas Recirculation (EGR);
• Use of Ultra-Low Sulfur Fuel;

1 UAC R307-401-4
2 Non-Emergency regulated per 40 CFR 60.4201, Emergency regulated by 40 CFR 60.4202, and General Requirements
regulated per 40 CFR 60.4203.
3 Database accessed January 30, 2024.

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• Diesel Particulate Filter (DPF);
• Diesel Oxidation Catalyst (DOC); and
• Selective Catalyst Reduction (SCR).
5.1.2 Diesel-Fired Engines Step 2 – Eliminate Technically Infeasible Options
Limited Hours of Operation
One of the options to control the emissions of all pollutants released from emergency generator engines is to
limit the hours of operation for the equipment. Due to the designation of this equipment as emergency
equipment, only 100 hours of operation for maintenance and testing are permitted per NSPS Subpart IIII.
Therefore, limiting hours of operation is considered technically feasible.
Good Combustion Practices
GCP refers to the operation of engines at high combustion efficiency, which reduces the products of incomplete
combustion, such as VOC and CO. Emergency generator engines are designed to achieve high combustion
efficiency when maintained and operated according to the manufacturer’s written instructions. GCP are
considered technically feasible.
Exhaust Gas Recirculation
NOx reduction can be achieved through recirculating exhaust into the engine. EPA tests have demonstrated
NOX reduction up to 50 percent if the engine timing is retarded, but test results are accompanied by an
increase in particulates.4 Computer based control schemes can assist in NOX reduction with associated timing
retardation, but EGR can also result in heat rejection, reduced power density, and lower fuel economy. Exhaust
gas recirculation is considered technically infeasible.
Diesel Particulate Filters
This simple technology is placed in the exhaust pathway to prevent the release of particulate and may be
coated with a catalyst to further capture hydrocarbon emissions. According to EPA’s Response to Public
Comments on Notice of Reconsideration of NESHAP for RICE and NSPS for Stationary ICE, “Diesel particulate
filters are also proven, commercially available technology…and are capable of reducing diesel PM by 90
percent or more.”5 Additionally, the California Air Resources Board (CARB) was able to determine that this
technology was technically feasible for emergency and prime engines through obtaining several vendor
quotes.6 This technology is considered technically feasible.
Diesel Oxidation Catalyst
A DOC utilizes a catalyst such as platinum or palladium to oxidize VOC emissions in the engine’s exhaust to
carbon dioxide (CO2) and water. Use of a DOC can result in approximately 90 percent reduction in VOC

4 U.S. EPA Control of Heavy-Duty Diesel NOX Emissions by Exhaust gas recirculation, Office of Mobile Source Air Pollution
Emissions Control Technology Division, August 1985
5 Response to Public Comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines and New Source Performance Standards for Stationary Internal
Combustion Engines, EPA Docket EPA-HQ-OAR-2008-0708, June 16, 2014
6 Response to Public Comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines and New Source Performance Standards for Stationary Internal
Combustion Engines, EPA Docket EPA-HQ-OAR-2008-0708, June 16, 2014

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emissions.7 In addition to controlling VOC, a DOC also has the potential to reduce PM emissions by 30 percent
(based on the concentration of soluble organics).8 However, the full reduction potential requires a minimum
operating temperature of 150 ºC (300 ºF).9 Similarly, U.S. EPA recommends if an engine emits extremely high
levels of PM and/or idles for long periods of time, an exhaust backpressure monitoring and operator
notification system may be installed to notify the operator when maintenance is needed.10 For this reason,
DOC control efficiencies are expected to be relatively low during the first 20 - 30 minutes after engine start
up, in fact U.S. EPA considered this method of aftertreatment to be generally unsuitable for backup use.11
Since operation of emergency engines typically only includes short duration runs and AT&T does not require
the engine to be brought to full load for monthly maintenance and testing, DOC is considered technically
ineffective for maintenance and testing.12
Selective Catalytic Reduction
SCR systems introduce a liquid reducing agent such as ammonia or urea into an engine’s flue-gas stream prior
to a catalyst. The catalyst reduces the temperature needed to initiate the reaction between the reducing agent
and NOX to form nitrogen and water. Additional variations including non-selective catalytic reduction (NSCR)
and selective non-catalytic reduction (SNCR) may be used but are not considered standard industry practice
and are not listed in the RBLC, thus SCR remains the focus of this technical analysis.

For SCR systems to function effectively, exhaust temperatures must be high enough (480 °F to 800 °F) to
enable catalyst activation, which will be accounted for in operation.13 For this reason, SCR control efficiencies
are expected to be relatively low during the first 20 - 30 minutes after engine start up. Since operation of
emergency engines typically only includes short duration runs for maintenance and testing, SCR is considered
technically ineffective for maintenance and testing.
5.1.3 Diesel-Fired Engines Step 3 – Ranking of Remaining Control Technologies
by Control Effectiveness
Effective control technologies for diesel engines are listed in the following table:

7 U.S. EPA, Alternative Control Techniques Document: Stationary Diesel Engines, March 5, 2010, p. 41.
(https://www.epa.gov/sites/production/files/2014-02/documents/3_2010_diesel_eng_alternativecontrol.pdf)
8 Response to Public Comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines and New Source Performance Standards for Stationary Internal
Combustion Engines, EPA Docket EPA-HQ-OAR-2008-0708, June 16, 2014
9 U.S. EPA’s Technical Bulletin for Diesel Oxidation Catalyst Installation, Operation, and Maintenance, EPA-420-F-10-030
published in May 2010.
10 Ibid.
11 Response to Public Comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines and New Source Performance Standards for Stationary Internal
Combustion Engines, EPA Docket EPA-HQ-OAR-2008-0708, Page 85, June 16, 2014
12 Annual testing requires the engines being brought to full load, but this is a small percentage of the overall maintenance and
testing operation time.
13 EPA Air Pollution Control Technology Fact Sheet for Selective Catalytic Reduction (SCR), EPA-452/F-03-032

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Table 5-1 Emergency Engine Controls Feasibility

Control
Technically
Feasible?
(Yes/No)
Limited Hours of Operation Yes
GCP Yes
EGR No
DPF Yes
DOC No
SCR No

The engine proposed meet the NSPS standards. Additionally, all units proposed will operate for limited hours,
using good combustion practices, diesel particulate filters, and fueled by ultra-low sulfur diesel.
5.1.4 Diesel-Fired Engine Step 4 – Evaluate Most Effective Controls and Document
Results
In order to ensure a complete analysis is presented AT&T has conducted a cost analysis for a new replacement
30kW engine that would meet the most current Tier IV standards. This cost analysis focused on NOX as the
reduction potential for this pollutant is greater than all other criteria pollutants. Based on a cost estimate from
a reliable vendor, the approximate total capital investment of a new 30kW engine is $19,000. Further, based
on U.S. EPA’s Alternative Control Techniques Document: Stationary Diesel Engines, the approximate operating
labor, maintenance, brake specific fuel consumption, and catalyst cost is $4 per horsepower.14 After
considering economic factors and other annual costs the calculated cost per ton removed is $123,413 per ton
removed. AT&T proposes that this is not cost effective and was not further considered. A full cost analysis is
included in Appendix C.
5.1.5 Diesel-Fired Engine Step 5 – Select BACT
AT&T uses all technically and economically feasible controls which generally include engine design consistent
with NSPS IIII (post-2006), EPA Tier rating, DPF, limited hours of operation, good combustion practices and/or
use of ultra-low sulfur fuel. Exact emission rates, reflecting this BACT, are included in the emission calculations.
5.2 Organic Liquid Storage Tank
5.2.1 Organic Liquid Storage Tank Step 1- Identify Potential Control Technologies
Emissions from fixed roof storage tanks result from displacement of headspace vapor during filling operations
(working losses) and from diurnal temperature and heating variations (breathing losses). AT&T reviewed a
variety of available sources, including but not limited to the RBLC. The identified control methods for tanks of
this size and vapor pressure included good operating and maintenance practices and submerged filling.

14 EPA Contract No. EP-D-07-019, Published March 5, 2010

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5.2.2 Organic Liquid Storage Tank Steps 2 - 4
Good Operating and Maintenance Practices
Good operating and maintenance practices refers to minimizing losses due to changes in temperature or
barometric pressure by, where possible, placing the tank indoors, in a basement, or buried underground.
Diesel storage tanks are designed to minimize working and breathing losses when maintained and operated
according to the manufacturer’s written instructions. Good operating and maintenance practices are
considered technically feasible.

As this tank is buried underground, minimal temperature changes are to be expected. Additionally, as the
diesel fuel is used only in the case of an emergency, it is a low throughput tank and therefore already
minimizes the frequency of filling and the associated emissions. AT&T uses good operating and maintenance
on the diesel tank.
Submerged Filling
During submerged loading, the fill pipe opening is below the liquid surface level and liquid turbulence is
controlled significantly, resulting in much lower vapor generation than encountered during splash loading.15
While technically feasible, due to the very low emission rate, it has been assumed that the retrofit of this
technology will be economically infeasible.
5.2.3 Organic Liquid Storage Tank Step 5
AT&T proposes good operating and maintenance practices meets BACT.

15 EPA AP-42 Section 5.2 Transportation and Marketing of Petroleum Liquids

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6. EMISSION IMPACT ANALYSIS
Table 6-1 compares criteria pollutant total proposed emissions to applicable modeling thresholds contained in R307-403-4 through 7, and
R307-410-4.
Table 6-1. Facility-Wide Emissions and Comparison to Major Source and Modeling Thresholds.
Unit Group Potential Annual Emissions (tpy)
NOx CO PM10 PM2.5 SO2 VOC Total HAP
Currently Permitted Units
Emergency Generators 8.51 1.94 0.27 0.27 4.25E-03 0.27 3.90E-03
Previously accounted for Tank - - - - - 4.45E-04 -
Proposed Units
Emergency Generator 0.42 0.09 0.03 0.03 1.63E-04 0.03 3.56E-04
Actual Tank - - - - - 1.11E-03 9.81E-05
Currently Permitted and to be Removed
Three Emergency Generators 0.47 0.10 3.32E-02 3.32E-02 1.83E-04 3.79E-02 4.00E-04
Totals
New Site Totals 8.46 1.93 0.26 0.26 4.23E-03 0.27 3.96E-03
Current Permitted PTE1 8.51 1.94 0.27 0.27 0.17 0.27 3.90E-03
Proposed Change in PTE -0.05 -0.01 -0.01 -0.01 -0.17 0.00 5.53E-05
Major Source Thresholds 100 100 100 70 70 70 25/10
Exceeding Major Source Thresholds?2,3 No No No No No No No
Modeling Thresholds4 40 - 15 - 40 - See HAPs Summary
Modeling Required? No No No No No No No
1. These emission totals represent the limit given in DAQE-AN0141260001-08
2. Major Source thresholds are defined by 40 CFR 51.165(a)(1)(iv)(A) and 40 CFR 52.21(b)(1)(i)(b)
3. Total HAP Threshold is stated in 40 CFR Section 63.2 under definition of a Major Source.
4. Modeling Limit is stated in UDAQ Emissions Impact Assessment Guidelines under Table 1: Total Controlled Emission Rates for New Sources.

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Table 6-1. Facility-Wide HAP Emissions and Comparison to Modeling Thresholds
Pollutant Facility Total PTE Before Project (tpy)
Facility Total PTE After Project (tpy)
Change in Facility Total PTE (tpy) Change in Facility Total PTE (lb/hr) ETV1 (lb/hr) Modeling Required?
Acetaldehyde 1.40E-04 1.31E-04 -9.00E-06 -3.60E-05 6.94 No
Acrolein 2.83E-05 2.72E-05 -1.09E-06 -4.34E-06 - -
Benzene 1.92E-03 1.91E-03 -8.62E-06 -3.45E-05 0.32 No
Formaldehyde 3.10E-04 2.96E-04 -1.38E-05 -5.54E-05 0.06 No
Toluene 7.03E-04 7.24E-04 2.15E-05 8.61E-05 14.92 No
Xylenes 4.83E-04 5.57E-04 7.35E-05 2.94E-04 - -
1,3-Butadiene 4.13E-06 3.67E-06 -4.59E-07 -1.84E-06 0.29 No
Other HAPs 3.14E-04 3.17E-04 3.29E-06 1.32E-05 - -

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7. EMISSION IMPACT ANALYSIS
7.1 Offset Applicability
7.1.1 PM2.5 Offsets
PM2.5 offsets are applicable for major modifications of sources located within or impacting a PM2.5
nonattainment area of the NAAQS. A major modification in a serious nonattainment area is defined in R307-
403-5(2)(c) as “a rate of emissions that would equal or exceed 10 tons per year (tpy) of direct PM2.5, 40 tpy
of sulfur dioxide, 40 tpy of nitrogen oxides, or 40 tpy of volatile organic compounds (VOC)”. The proposed
modifications do not exceed the limits of PM2.5, SO2, NOX , or VOCs. AT&T is therefore not subject to the offset
requirements of R307-403.

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8. REGULATORY ANALYSIS
8.1 UDAQ Air Quality Rules
AT&T has evaluated the applicability of each rule under the Utah Administrative Code (UAC) Title R307. Rules
generally applicable to AT&T but not affected by this project have not been addressed.
Table 8-1. Evaluation of UDAQ Air Quality Rules
Reference Regulation Name Applicability
Yes No
R307-101 General Requirements X
R307-102 1 General Requirements: Broadly Applicable
Requirements X
R307-103 1 Administrative Procedures X
R307-104 2 Conflict of Interest X
R307-105 1 General Requirements: Emergency controls X
R307-107

General Requirements: Breakdowns X
R307-110 1 General Requirements: State Implementation
Plan X
R307-115 1 General Conformity X
R307-120 General Requirements: Tax Exemption for Air
Pollution Control Equipment X
R307-121 General Requirements: Clean Air and Efficient
Vehicle Tax Credit X
R307-122 General Requirements: Heavy Duty Vehicle Tax
Credit X
R307-123 General Requirements: Clean Fuels and Vehicle
Technology Grant and Loan Program X
R307-124 General Requirements: Conversion to Alternative
Fuel Grant Program X
R307-125 Clean Air Retrofit, Replacement, and Off-Road
Technology Program X
R307-130 1 General Penalty Policy X
R307-135 Enforcement Policy for Asbestos Hazard
Emergency Response Act X
R307-150 Emission Inventories X
R307-165

Stack Testing X
R307-170 Continuous Emission Monitoring Program X
R307-201 Emission Standards: General Emission Standards X
R307-202 Emission Standards: General Burning X

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Reference Regulation Name Applicability
Yes No
R307-203

Emission Standards: Sulfur Content of Fuels X
R307-204 Emission Standards: Smoke Management X
R307-205 Emission Standards: Fugitive Emissions and
Fugitive Dust X
R307-206 Emission Standards: Abrasive Blasting X
R307-207 Residential Fireplaces and Solid Fuel Burning
Devices X
R307-208 Outdoor Wood Boilers X
R307-210 1 Standards of Performance for New Stationary
Sources X
R307-214 1 National Emission Standards for Hazardous Air
Pollutants X
R307-220 Emission Standards: Plan for Designated Facilities X
R307-221 Emission Standards: Emission Controls for
Existing Municipal Solid Waste Landfills X
R307-222 Emission Standards: Existing Incinerators for
Hospital, Medical, Infectious Waste X
R307-223 Emission Standards: Existing Small Municipal
Waste Combustion Units X
R307-224 Mercury Emission Standards: Coal Fired Electric
Generating Units X
R307-230

NOX Emission Limits for Natural Gas-Fired Water
Heaters X
R307-240 Prescribed Burning X
R307-250 Western Backstop Sulfur Dioxide Trading Program X
R307-301 Utah and Weber Counties: Oxygenated Gasoline
Program as a Contingency Measure X
R307-302 Solid Fuel Burning Devices X
R307-303 Commercial Cooking X
R307-304

Solvent Cleaning X
R307-305

Nonattainment and Maintenance Areas for PM10:
Emission Standards X
R307-306
PM10 Nonattainment and Maintenance Areas:
Abrasive Blasting X
R307-307

Road Salting and Sanding X

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Reference Regulation Name Applicability
Yes No
R307-309
Nonattainment and Maintenance Areas for PM10
and PM2.5: Fugitive Emissions and Fugitive Dust X
R307-310 Salt Lake County: Trading of Emission Budgets
for Transportation Conformity X
R307-311 Utah County: Trading of Emission Budgets for
Transportation Conformity X
R307-312
Aggregate Processing Operations for PM2.5
Nonattainment Areas X
R307-315 NOx Emission Controls for Natural Gas-Fired
Boilers 2.0-5.0 MMBtu X
R307-316 NOx Emission Controls for Natural Gas-Fired
Boilers Greater than 5.0 MMBtu X
R307-320

Ozone Maintenance Areas and Ogden City:
Employer Based Trip Reduction Program X
R307-325

Ozone Nonattainment and Maintenance Areas:
General Requirements X
R307-326
Ozone Nonattainment and Maintenance Areas:
Control of Hydrocarbon Emissions in Petroleum
Refineries
X
R307-327 Ozone Nonattainment and Maintenance Areas:
Petroleum Liquid Storage X
R307-328

Gasoline Transfer and Storage X
R307-335

Degreasing X
R307-341

Ozone Nonattainment and Maintenance Areas:
Cutback Asphalt X
R307-342

Adhesives and Sealants X
R307-343 Wood Furniture Manufacturing Operations X
R307-344 Paper, Film, and Foil Coatings X
R307-345 Fabric and Vinyl Coatings X
R307-346 Metal Furniture Surface Coatings X
R307-347 Large Applicable Surface Coatings X
R307-348 Magnet Wire Coatings X
R307-349 Flat Wood Panel Coatings X
R307-350 Miscellaneous Metal Parts and Products Coatings X
R307-351

Graphic Arts X
R307-352 Metal Container, Closure, and Coil Coatings X
R307-353 Plastic Parts Coatings X
R307-354 Automotive Refinishing Coatings X

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Reference Regulation Name Applicability
Yes No
R307-355 Aerospace Manufacture and Rework Facilities X
R307-356 Appliance Pilot Light X
R307-357 Consumer Products X
R307-361

Architectural Coatings X
R307-401 1 Permit: New and Modified Sources X
R307-403 1

Permits: New and Modified Sources in
Nonattainment and Maintenance Areas X
R307-405 Permits: Major Sources in Attainment or
Unclassified Areas (PSD) X
R307-406 2 Visibility X
R307-410

Emissions Impact Analysis X
R307-414

Fees for Approval Orders X
R307-415 1 Permits: Operating Permit Requirements X
R307-417 Acid Rain Sources X
R307-420

Permits: Ozone Offset Requirements in Davis and
Salt Lake County Counties X
R307-421

Permits: PM10 Offset Requirements in Salt Lake
County and Utah County X
R307-424 Mercury Requirements for Electric Generating
Units X
R307-501 to
511
Oil and Gas Industry X
R307-801

Utah Asbestos Rule X
R307-840

Lead-Based Paint Program Purpose, Applicability,
and Definitions X
R307-841 Residential Property and Child-Occupied Facility
Renovation X
R307-842

Lead-Based Paint Activities X
1. The subject rule is or could be applicable to AT&T; however, this rule is not specific to operational
compliance requirements and is therefore not discussed in this NOI air permit application.
2. At the time of submission of this NOI air permit application, this rule does not apply.
3. Applicable NSPS and NESHAP regulations are detailed under appropriate project headings.
8.1.1 UAC R307-101 General Requirements:
Chapter 19-2 and the rules adopted by the Air Quality Board constitute the basis for control of air pollution
sources in the state. These rules apply and will be enforced throughout the state and are recommended for
adoption in local jurisdictions where environmental specialists are available to cooperate in implementing rule
requirements.

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NAAQS, NSPS, National Prevention of Significant Deterioration of Air Quality (PSD) standards, and the
NESHAP apply throughout the nation and are legally enforceable in Utah.

AT&T will comply and conform to the definitions, terms, abbreviations, and references used in the R307-101
and 40 CFR.
8.1.2 UAC R307-107 General Requirements: Breakdowns
AT&T will report breakdowns within 24 hours via telephone, electronic mail, fax, or other similar method and
provide detailed written description within 14 days of the onset of the incident to UDAQ. Breakdown reports
will include all reporting details outlined in R307-107-2, including, but not limited to, the cause and nature of
the event, estimated quantity of emissions, and time of emissions.
8.1.3 UAC R307-201 Emission Standards: General Emission Standards
All rules applicable to AT&T are incorporated by reference from 40 CFR Part 60. Applicability and requirements
for these rules are outlined in Section 8.2 of this submittal.
8.1.4 UAC R307-203 Emission Standards: Sulfur Content of Fuels
Sulfur emissions shall be no more than 0.85 pounds sulfur per million gross BTU heat input for any oil. The
following specifications for each purchase of fuel oil are recorded: weight percent sulfur, gross heating value
(Btu per unit volume), and density. These parameters shall be determined in accordance with the methods of
the American Society for Testing and Materials (ASTM). Records of fuel sulfur content shall be kept for all
periods when the Facility is in operation and shall be made available to the Director upon request and shall
include a period of two years ending with the date of the request.

AT&T will record the following specifications for each purchase of fuel oil in the event that it will be used:
weight percent sulfur, gross heating value (Btu per unit volume), and density. In doing so, AT&T will meet
the emission standards for sulfur content of fuel as described in R307-203-1.(1)(a).
8.1.5 UAC R307-309 Nonattainment and Maintenance Areas for PM10 and PM2.5:
Fugitive Emissions and Fugitive Dust
AT&T is expected to be a fugitive source of PM10 emissions and is located in an area of PM10 nonattainment.
Therefore, AT&T will comply with any requirements that are issued in its AO limiting opacity of fugitive
emissions and requiring opacity observations as specified in R307-309-4.

8.1.6 UAC R307-401-8 Permits: Permit New and Modified Sources – Approval
Order:
(1) The director will issue an AO if all conditions and regulations have been met.
(a) The degree of pollution control for emissions, to include fugitive emissions and fugitive
dust, is at least best available control technology. When determining best available control
technology for a new or modified source in an ozone nonattainment or maintenance area that
will emit VOC or NOX , best available control technology shall be at least as stringent as any
Control Technique Guidance document that has been published by EPA that is applicable to
the source.
(b) The proposed installation will meet the applicable requirements of:

AT&T / NOI Application
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(i) R307-403, Permits: New and Modified Sources in Nonattainment Areas and
Maintenance Areas;
(ii) R307-405, Permits: Major Sources in Attainment or Unclassified Areas (PSD);
(iii) R307-406, Visibility;
(iv) R307-410, Emissions Impact Analysis;
(v) R307-420, Permits: Ozone Offset Requirements in Davis and Salt Lake Counties;
(vi) R307-210, National Standards of Performance for New Stationary Sources;
(vii) National Primary and Secondary Ambient Air Quality Standards;
(viii) R307-214, National Emission Standards for Hazardous Air Pollutants;
(ix) R307-110, General Requirements. Utah State Implementation Plan; and
(x) All other provisions of R307.
(2) AT&T’s AO will require that all pollution control equipment be adequately and properly maintained.
(3) Receipt of an AO does not relieve any owner or operator of the responsibility to comply with the
provisions of R307 or the State Implementation Plan.

BACT provisions specified in UAC R307-401 have been applied through control equipment installed and
monitoring conditions.

AT&T will comply with all applicable requirements detailed above.
8.1.7 UAC R307-414 Permits: Fees for Approval Orders:
Fees associated with the submission of this NOI air permit application are addressed in Section 1 of this
submittal.
8.2 Federal Rules: National Emission Standards for Hazardous Air
Pollutants
The NESHAP federal regulations found in Title 40 Parts 61 and 63 of the CFR are emission standards for HAPs.
NESHAP are applicable to both major sources of HAPs (facilities that exceed the major source thresholds of
10 tpy of a single HAP and 25 tpy of any combination of HAPs from stationary sources) as well as non-major
sources (termed “area sources”). NESHAP apply to sources in specifically regulated industrial source
classifications (Clean Air Act Section 112(d)) or on a case-by-case basis (Clean Air Act Section 112(g)) for
facilities not regulated as a specific industrial source type.

AT&T is an area source under the NSR program. As such, this document only addresses regulatory applicability
for area sources and does not include standards for major sources.
8.2.1 Subpart A – General Provisions
NESHAP Subpart A, General Provisions, contains national emissions standards for HAPs defined in Section
112(b) of the Clean Air Act. All affected sources, which are subject to another NESHAP are subject to the
general provisions of NESHAP Subpart A, unless specifically excluded by the source-specific NEHSAP. Subpart
A requires initial notification, performance testing, recordkeeping, and monitoring, provides reference
methods, and mandates general control device requirements for all other subparts. The following sections
detailing each subpart requirements also includes requirements that are referenced to Subpart A.

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8.2.2 Subpart ZZZZ – Stationary Reciprocating Internal Combustion Engines
NESHAP Subpart ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating
Internal Combustion Engines, applies to stationary reciprocating internal combustion engines (RICE) at major
and area sources of HAPs. Per 40 CFR 63.6590(a)(2)(iii), a stationary RICE at an area source of HAPs is new
if construction commenced after June 12, 2006. Thus, the proposed engine is considered a new stationary
RICE under NESHAP Subpart ZZZZ. Per 40 CFR 63.6590(c) and 40 CFR 63.6590(c)(1), new stationary RICE
located at an area source of HAP may show compliance with NESHAP ZZZZ by maintaining compliance with
NSPS IIII.16 AT&T is not a major source of HAPs, as total HAP emissions amount to less than 10 tons per
year for an individual HAP and less than 25 tons per year of total HAPs. By maintaining compliance with NSPS
IIII, AT&T can demonstrate compliance with NESHAP ZZZZ.
8.3 Federal Rules: New Source Performance Standards
NSPS requires new, modified, or reconstructed sources to control emissions to the level achievable by the
best demonstrated technology as specified in the applicable provisions. Moreover, any source subject to NSPS
is also subject to the general provisions of NSPS Subpart A, except as noted. The following section details the
applicability of NSPS regulations to facility operations.
8.3.1 Subpart A-General Provisions
All affected sources subject to source-specific NSPS are subject to the general provisions of NSPS Subpart A
unless specifically excluded by the source-specific NSPS. Subpart A requires initial notification, performance
testing, recordkeeping, and monitoring, provides reference methods, and mandates general control device
requirements for all other subparts.
8.3.2 NSPS Subpart IIII – Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines
NSPS Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal Combustion
Engines, establishes requirements for stationary compression ignition internal combustion engines for which
construction, modification, or reconstruction commenced after July 11, 2005.

The provisions of this subpart are applicable to owners and operators of compression ignition internal
combustion engines which commenced construction after July 11, 2005 and were manufactured after April 1,
2006. The construction date is the date the engine was ordered by the owner or operator. The engine
powering the generator proposed in this application was constructed after the specified construction dates.
NSPS IIII is applicable to this engine.
Emission Limitation
• Emergency Engines
♦ Emergency stationary CI ICE with a displacement of < 10 liters per cylinder that are not fire pump
engines must comply with the emission standards for new nonroad CI engines in §60.4202(a), for
all pollutants, for the same model year and maximum engine power for their 2007 model year and
later emergency stationary CI ICE.17
• All Emergency Engines

16 NESHAP Subpart 40 CFR 63.6675.
17 40 CFR 60.4205(b).

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♦ These limitations must be met for the life of the engine.18
Fuel Requirements
• Owners and operators of stationary CI ICE subject to this subpart with a displacement of less than 30
liters per cylinder that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR
80.510(b) for nonroad diesel fuel, except that any existing diesel fuel purchased (or otherwise obtained)
prior to October 1, 2010, may be used until depleted.19
• The requirements of 40 CFR 80.510(b) are as follows:
 1) 15 ppm sulfur, and
 2) minimum cetane index of 40 or maximum aromatic content of 35 volume percent.
Monitoring Requirements
• Each CI ICE that does not meet the standards applicable to non-emergency engines, must install a
non-resettable hour meter prior to startup of the engine.20
• Each CI ICE equipped with a diesel particulate filter to comply with the emission standards in §60.4204,
the diesel particulate filter must be installed with a backpressure monitor that notifies the owner or
operator when the high backpressure limit of the engine is approached.21
Compliance Requirements
• Operate, maintain, install, and configure the stationary CI internal combustion engine and control
device according to the manufacturer's emission-related written instructions;22
• Change only those emission-related settings that are permitted by the manufacturer; 23
• Meet the requirements of 40 CFR 89, 94, and/or 1068;24
• Stationary CI internal combustion engine must comply with the emission standards specified in
§60.4204(b) or §60.4205(b).25
Emergency Engines 26
• The engine may be operated for 100 hours per calendar year for maintenance checks, readiness testing,
periods where there is a deviation of voltage or frequency of 5 percent or greater below standard
voltage or frequency, and/or up to 50 hours per calendar year in non-emergency situations.
• No limit for emergency usage of the engine in emergency situations.
Recordkeeping 27
• Using the non-resettable hour meter, a record of the engine's emergency operation must be kept. The
records must contain the time of operation and the reason the engine was in operation.

18 40 CFR 60.4206.
19 40 CFR 60.4207(b).
20 40 CFR 60.4209(a).
21 40 CFR 60.4209(b).
22 40 CFR 60.4211(a)(1).
23 40 CFR 60.4211(a)(2).
24 40 CFR 60.4211(a)(3).
25 40 CFR 60.4211(c).
26 40 CFR 60.4211(f).
27 40 CFR 60.4214(b)

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• AT&T also retains records to indicate that the engine is certified to the emission standards required for
the appropriate manufacture year and size.28

28 40 CFR 60.4211(c).

AT&T / NOI Application
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APPENDIX A. FORMS

Form 1 Date __________________
Notice of Intent (NOI) Application Checklist
Company __________________
Utah Division of Air Quality
New Source Review Section
Source Identification Information [R307-401-5]
1. Company name, mailing address, physical address and telephone number 
2. Company contact (Name, mailing address, and telephone number)
3.Name and contact of person submitting NOI application (if different than 2)
4.Source Universal Transverse Mercator (UTM) coordinates 
5. Source Standard Industrial Classification (SIC) code 
6.Area designation (attainment, maintenance, or nonattainment)
7.Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.)
8.Source size determination (Major, Minor, PSD)
9. Current Approval Order(s) and/or Title V Permit numbers 
NOI Application Information: [R307-401]










N/A 
N/A 
A.Air quality analysis (air model, met data, background data, source impact analysis) N/A 
1.Detailed description of the project and source process
2.Discussion of fuels, raw materials, and products consumed/produced
3.Description of equipment used in the process and operating schedule
4.Description of changes to the process, production rates, etc.
5.Site plan of source with building dimensions, stack parameters, etc.
6.Best Available Control Technology (BACT) Analysis [R307-401-8]
A.BACT analysis for all new and modified equipment
7.Emissions Related Information: [R307-401-2(b)]
A.Emission calculations for each new/modified unit and site-wide
(Include PM10, PM2.5, NOx, SO2, CO, VOCs, HAPs, and GHGs)
B.References/assumptions, SDS, for each calculation and pollutant
C.All speciated HAP emissions (list in lbs/hr)
8.Emissions Impact Analysis – Approved Modeling Protocol [R307-410]
A.Composition and physical characteristics of effluent
(emission rates, temperature, volume, pollutant types and concentrations)
9.Nonattainment/Maintenance Areas – Major NSR/Minor (offsetting only) [R307-403]
A.NAAQS demonstration, Lowest Achievable Emission Rate, Offset requirements
B.Alternative site analysis, Major source ownership compliance certification
10.Major Sources in Attainment or Unclassified Areas (PSD) [R307-405, R307-406]
B.Visibility impact analysis, Class I area impact
11.Signature on Application
N/A 
Note: The Division of Air Quality will not accept documents containing confidential information or data.
Documents containing confidential information will be returned to the Source submitting the application.
1 of 1
Form 2 Date _______
Company Information/Notice of Intent (NOI)
Utah Division of Air Quality
New Source Review Section
Application for: □ Initial Approval Order □Approval Order Modification
General Owner and Source Information
1.Company name and mailing address:
AT&T Communications of the Mountain
States, Inc. 1311 S Akard St, 12th Floor,
Dallas, TX 75202
Phone No.: ( )
Fax No.: ( )
2.Company** contact for environmental matters:
____________________________
Phone no.: ( )
Email: _______________________
** Company contact only; consultant or independent contractor contact
information can be provided in a cover letter
3.Source name and physical address (if different from
above):
_AT&T Communications of the
Mountain States, Inc. 1760 North Highway
38, Brigham City, Utah 84302-3711
__
Phone no.: ( )
Fax no.: ( )
4.Source Property Universal Transverse Mercator
coordinates (UTM), including System and Datum:
UTM:_________________________
X:____________________________
Y:____________________________
5.The Source is located in:__________________ County 6.Standard Industrial Classification Code (SIC)
__ __ __ __
7.If request for modification, AO# to be modified: DAQE #__________________ DATED: ____/____/____
8.Brief (50 words or less) description of process.
Electronic NOI
9.A complete and accurate electronic NOI submitted to DAQ Permitting Mangers Jon Black ([e-mail]) or Alan
Humpherys ([e-mail]) can expedite review process. Please mark application type.
Hard Copy Submittal Electronic Copy Submittal □ Both
Authorization/Signature
I hereby certify that the information and data submitted in and with this application is completely true, accurate and
complete, based on reasonable inquiry made by me and to the best of my knowledge and belief.
Signature: Title:
_______________________________________
Name (Type or print)
Telephone Number:
( )
Email:
Date:
Page 1 of 1
Form 4 Company____________________________
Project Information Site ______________________________
Utah Division of Air Quality
New Source Review Section
Process Data - For Modification/Amendment ONLY
1.Permit Number_______________________________
If submitting a new permit, then use Form 3
Requested Changes
2.Name of process to be modified/added:
_______________________________
End product of this process:
_______________________________
3.Permit Change Type: New Increase*
Equipment
Process
Condition Change ____________________
Other ______________________________
Other ______________________________
Other ______________________________
4.Does new emission unit affect existing
permitted process limits?
Yes No
5.Condition(s) Changing:
6.Description of Permit/Process Change**
7.New or modified materials and quantities used in process. **
Material Quantity Annually
8.New or modified process emitting units **
Emitting Unit(s) Capacity(s) Manufacture Date(s)
*If the permit being modified does not include CO2e or PM2.5, the emissions need to be calculated and submitted to DAQ, which may result in an
emissions increase and a public comment period.
**If additional space is required, please generate a document to accommodate and attach to form.
AT&T Communications of the Mountain States, Inc., located at 1760 North Highway 38 in Brigham City,
Box Elder County, Utah, is seeking to remove from operation three 15 kW emergency/standby diesel
powered generators [EGEN1; EGEN2; and, EGEN3], and update the capacity of diesel fuel storage tank
[Tank 1] from 4,000 gallons to 8,000 gallons. Additionally, the Site is requesting to operate a 40 kW
portable diesel powered generator [EGEN6].
8,000 gallons
40 kW
35,010 gallons/year
15 kW
15 kW
15 kW
Page 1 of 1
Company___________________________
Site _____________________________
Form 5
Emissions Information
Criteria/GHGs/ HAP’s
Utah Division of Air Quality
New Source Review Section
Potential to Emit* Criteria Pollutants & GHGs
Criteria Pollutants Permitted Emissions
(tons/yr)
Emissions Increases
(tons/yr)
Proposed Emissions
(tons/yr)
PM10 Total
PM10 Fugitive
PM2.5
NOx
SO2
CO
VOC
VOC Fugitive
NH3
Greenhouse Gases CO2e CO2e CO2e
CO2
CH4
N2O
HFCs
PFCs
SF6
Total CO2e
*Potential to emit to include pollution control equipment as defined by R307-401-2.
Hazardous Air Pollutants** (**Defined in Section 112(b) of the Clean Air Act )
Hazardous Air
Pollutant***
Permitted Emissions
(tons/yr)
Emission Increase
(tons/yr)
Proposed
Emission (tons/yr)
Emission Increase
(lbs/hr)
Total HAP
*** Use additional sheets for pollutants if needed
0.0039 0.00 0.0039
See Attached for Emission Information
See Attached for Emission Information
See Attached for Emission Information
Utah Division of Air Quality
New Source Review Section Company: ___________________
Site/Source: _________________
Form 17 Date: _______________________
Diesel Powered Standby Generator
Company Information
1. Company Name and Address:
____________________________________________
____________________________________________
____________________________________________
____________________________________________
Phone Number: _______________________________
Fax Number: _______________________________
2. Company Contact:
____________________________________________
____________________________________________
____________________________________________
____________________________________________
Phone Number: _______________________________
Fax Number: _______________________________
3. Installation Address:
____________________________________________ County where facility is located: __________________
____________________________________________
____________________________________________ Latitude, Longitude and UTM Coordinates of Facility
____________________________________________ __________________________________________
Phone Number: _______________________________ __________________________________________
Fax Number: _______________________________
Standby Generator Information
4. Engines:
Maximum Maximum Emission Rate Date the engine
Manufacturer Model Rated Hours of Rate of NOx was constructed
Horsepower or Kilowatts Operation grams/BHP-HR or reconstructed
___________________________________40 kW__________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
Attach Manufacturer-supplied information
5. Calculated emissions for this equipment:
PM2.5____________ Lbs/hr _____________Tons/yr
SOx ____________ Lbs/hr______________Tons/yr
VOC ____________Lbs/hr______________Tons/yr
PM10____________ Lbs/hr _____________Tons/
yr NOx________See_____Lbs/
hr______________Tons/yr CO
_____________Lbs/hr______________Tons/yr
CO2 ____________Tons/yr
CH4 ____________ Tons/yr
HAPs___________ Lbs/hr (speciate)__________Tons/yr
(speciate) Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
AT&T Communications of the Mountain States, Inc.
1311 S Akard St, 12th Floor, Dallas, TX 75202
415-454-9282
281-664-4201
214-208-5264
281-664-4201
AT&T Communications of the Mountain States, Inc.
1760 North Highway 38, Brigham City, Utah 84302
Box Elder
415-454-9282
281-664-4201
UTM: 4,599,785 meters Northing, 415,346 meters Easting, Zone 12
Latitude: 41.5471653379°; Longitude: -112.0149752101°
EGEN6
2048/1800/GPerkins 500 hours/year December 1998
Julianne Barnum
AT&T Communications of the Mountain States,
Inc. 1311 S Akard St, 12th Floor, Dallas, TX
75202
AT&T Communications of the Mountain States, Inc.
Brigham City, Box Elder County, Utah
1/9/2024
See Attached for Emission Information
Instructions Form 17 - Diesel Powered Standby Generator
Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in filling out
this form. Ask to speak with a New Source Review engineer. We will be glad to help!
Lines 1 Fill in the name, address, phone number, and fax number of the business applying for the
and 2: permit exemption.
Line 3 Fill in the address where the equipment will be located. Directions to business if needed for remote locations,
i.e., five miles south of Deseret on highway 101, turn left at farmhouse, go 1.5 miles. Identify the county the
equipment will be located. Also enter the latitude, longitude and UTM coordinates of the facility.
Line 4 Fill in the manufacturer, model, maximum rated horsepower or kilowatts, maximum hours of operation, emission
rate for NOx in grams/BHP-hr, and the date the engine was constructed or reconstructed. Attach manufacturer
emission information.
Note: Maximum rated horsepower not to exceed 1000hp or 750 kilowatts. Also maximum hours not to exceed
300 hours.
Line 5 Supply calculations for all criteria pollutants, greenhouse gases and hazardous air pollutants. Use EPA AP-42
or manufacturers’ data to complete your calculations. Fill in the name, address, phone number, and fax number
of the business applying for the
U:\aq\ENGINEER\GENERIC\Forms 2010\Form17 Diesel-fired Standby Generators.doc
Revised 12/20/10
Page 1 of 2
New Source Review Section
Date: _____________________________
Utah Division of Air Quality
Company: _________________________
Site/Source:________________________
Form 20
rganic Liquid Storage Tank O
Equipment
1. Tank manufacturer: ___________________________2. Identification number: _____________________
3. Installation date: ______________________________4. Volume: __________________________ gallons
5. Inside tank diameter: ______________________ feet 6. Tank height: ________________________ feet
7. True vapor pressure of liquid: _______________ psia 8. Reid vapor pressure of liquid: ____________ psi
9. Outside color of tank: __________________________10. Maximum storage temperature: __________ FO
11. Average throughput: ____________ gallons per year 12. Turnovers/yearly ____ Monthly ____ Weekly ___
13. Average liquid height (feet): _____________________ Yes No Number ______14.Access hatch: □ □
15. T
a. P
r
b. S
Type: ________________________________
16. D
ll Yes No Number_____
ll
ak
ype of Seals:
rimary seals:
□Mechanical shoe
□Resilient filled
□Liquid filled
□Vapor mounted
□Liquid mounted
□ Flexible wipe
econdary seal:
eck Fittings:
□Gauge float we □
Gauge hatch/
sample we □ Yes □ No Number_____
Roof drains □ Yes □ No Number_____
Rim vents □ Yes □ No Number_____
Vacuum bre □ Yes □ No Number_____
Roof leg □ Yes □ No Number_____
Ladder well □ Yes □ No Number_____
Column well □ Yes □ No Number_____
Other:_________________________________
17. S
Deck Fitting Category: ________________________
18. T
______________________________________
hell Characteristics:
Condition: _________________________________
Breather Vent Settings: ________________________
Tank Construction: ___________________________
Roof Type: __________________________________
Deck Construction: ___________________________
ype of Construction:
□Vertical Fixed Roof
□Horizontal Fixed Roof
□Internal Floating Roof
□External Floating Roof
□Other (please specify)
19. Additional Controls:
Gas Blanket Venting Carbon Adsorption Thermal Oxidation Other:_______________□□ □□□
20.Single Liquid Information
Liquid Name: __________________________________
CAS Number: __________________________________
Avg. Temperature: ______________________________
Vapor Pressure: ________________________________
Liquid Molecular Weight: ________________________ Liquid Molecular Weight: ________________________
Liquid Name: __________________________________
CAS Number: __________________________________
Avg. Temperature: ______________________________
Vapor Pressure: ________________________________
Tank 1
8,000
31,
68476-30-2
Fuel Oil No. 2
675 F
0.1 PSI
AT&T Communications of the Mountain States, Inc.
Brigham City, Box Elder County, Utah
1/9/2024
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Vapor Pressure: ________________________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22. C
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
alculated emissions for this device:
VOC _________Lbs/hr_____ Tons/yr
HAPs_________Lbs/hr (speciate)______Tons/yr (speciate)
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
on number that will appear on the tank.
s or barrels.
r in feet.
liquid (psi).
ach during storage (degrees Fahrenheit).
emptied and refilled per year, month or week.
ss hatches and the number.
17. Specify condition of the tank, also include the following:
d roof tanks
el construction sizes and seam length
olled, or detail
22.ations for all criteria pollutants and HAPs. Use AP-42 or manufacturers’ data to complete your
calculations.
ENERIC\Forms 2010\Form20 Organic Liquid Storage Tanks.doc
Revised 12/20/10
Call the Division of Air Quality (DAQ) at [phone] if you have problems
1. Indicate the tank manufacturer's name.
2.Supply the equipment identificati
3. Indicate the date of installation.
4.Indicate the capacity of the tank in gallon
5. Specify the inside tank diamete
6. Specify the tank height in feet.
7.Indicate the true vapor pressure of the liquid (psia).
8.Indicate the Reid vapor pressure of the
9. Indicate the outside color of the tank.
10.Supply the highest temperature the liquid will re
11. Indicate average annual throughput (gallons).
12.Specify how many times the tank will be
13. Specify the average liquid height (feet).
14.Indicate whether or not the tank has acce
15. Indicate what type of seals the tank has.
16.Indicate what types of deck fittings are installed.
Breather vent settings in (psig) for fixe
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or pan
Deck fitting category; typical, contr
18. Indicate the type of tank construction.
19.Indicate other types of additional controls which will be used.
20.Provide information on liquid being stored, add additional sheets as necessary.
21.Provide information on chemicals being stored, add additional sheets as necessary.
Supply calcul
f:\aq\ENGINEER\G
See Attached for Emission Information

AT&T / NOI Application
Trinity Consultants B-1
APPENDIX B. EMISSIONS CALCULATION

Table 2-1. Stationary Generator Information
Parameter Value Units
Annual Hours of Operation (per Generator):500 hr/yr
500 kW
671 hp
Number of Generators:2
Fuel1:Fuel Oil No. 2
% Sulfur2:0.0015
Fuel Consumption (per Generator)1:33.53 gal/hr
Maximum Annual Fuel Consumption (per Generator):16,765 gal/yr
1. Based on manufactorer specifications.
2. Per 40 CFR 60 Subpart IIII, maximum sulfur content of ULSD is 15 ppm (i.e. 0.0015%).
Table 2-2. Stationary Generator Emissions
Pollutant
Emission
Factor1
(lb/hp-hr)
Potential
Emissions per
Generator3
(lb/hr)
Total Potential
Emissions for
Both Generators4
(tpy)
NOx 0.024 16.09 8.05
CO 5.50E-03 3.69 1.84
PM102 7.00E-04 0.47 0.23
PM2.52 7.00E-04 0.47 0.23
SO2 1.21E-05 0.01 0.00
VOC 7.05E-04 0.47 0.24
1. Source: EPA AP 42, Volume I, Fifth Edition, Table 3.4-1.
2. Conservatively assumed PM=PM10=PM2.5
3. Sample emissions calculation: Potential Emissions (lb/hr) = Emission Factor (lb/hp-hr) * Output Capacity (hp)
Table 2-3. Proposed Portable Generator Information
Parameter Value Units
Annual Hours of Operation (per Generator):500 hr/yr
40 kW
54 hp
Number of Generators:1
Fuel:Fuel Oil No.2
% Sulfur2:0.0015
Fuel Consumption (per Generator)1:2.96 gal/hr
Maximum Annual Fuel Consumption (per Generator):1,480 gal/yr
1. Based on manufactorer specifications.
2. Per 40 CFR 60 Subpart IIII, maximum sulfur content of ULSD is 15 ppm (i.e. 0.0015%).
Output Capacity (per Generator)1:
Output Capacity (per Generator)1:
4. Sample emissions calculation: Potential Emissions (tpy)= Potential Emissions (lb/hr) * Annual Hours of Operation (hr/yr)
* 1/2,000 (ton/lbs) * Number of Generators
Table 2-4. Proposed Portable Generator Emissions
Pollutant
Emission
Factor1
(lb/hp-hr)
Potential
Emissions per
Generator
(lb/hr)3
Total Potential
Emissions
(tpy)4
NOx 0.031 1.66 0.42
CO 6.68E-03 0.36 0.09
PM102 2.20E-03 0.12 0.03
PM2.52 2.20E-03 0.12 0.03
SO2 1.21E-05 6.51E-04 1.63E-04
VOC 2.51E-03 0.13 0.03
1. Source: EPA AP 42, Volume I, Fifth Edition, Table 3.3-1.
2. Conservatively assumed PM10=PM2.5
3. Sample emissions calculation: Potential Emissions (lb/hr) = Emission Factor (lb/hp-hr) * Output Capacity (hp)
Table 2-5. To be Removed Stationary Generator Information
Parameter Value Units
Annual Hours of Operation (per Generator):500 hr/yr
15 kW
20 hp
Number of Generators:3
Fuel1:Fuel Oil No. 2
% Sulfur2:0.0015
Fuel Consumption (per Generator)1:1.01 gal/hr
Maximum Annual Fuel Consumption (per Generator):505 gal/yr
1. Based on manufactorer specifications.
2. Per 40 CFR 60 Subpart IIII, maximum sulfur content of ULSD is 15 ppm (i.e. 0.0015%).
Table 2-6. To be Removed Stationary Generator Emissions
Pollutant
Emission
Factor1
(lb/hp-hr)
Potential
Emissions per
Generator3
(lb/hr)
Total Potential
Emissions for All
Three Generators4
(tpy)
NOx 0.031 0.62 0.47
CO 6.68E-03 0.13 0.10
PM102 2.20E-03 0.04 0.03
PM2.52 2.20E-03 0.04 0.03
SO2 1.21E-05 0.00 1.83E-04
VOC 2.51E-03 0.05 0.04
1. Source: EPA AP 42, Volume I, Fifth Edition, Table 3.3-1.
2. Conservatively assumed PM10=PM2.5
3. Sample emissions calculation: Potential Emissions (lb/hr) = Emission Factor (lb/hp-hr) * Output Capacity (hp)
Output Capacity (per Generator)1:
4. Sample emissions calculation: Potential Emissions (tpy)= Potential Emissions (lb/hr) * Annual Hours of Operation (hr/yr)
* 1/2,000 (ton/lbs) * Number of Generators
4. Sample emissions calculation: Potential Emissions (tpy)= Potential Emissions (lb/hr) * Annual Hours of Operation (hr/yr)
* 1/2,000 (ton/lbs) * Number of Generators
Brigham City, UT Facility
Potential Emissions Calculation
Table 1. Emissions Summary
NOx CO PM10 PM2.5 SO2 VOC Total HAP
Emergency Generators 8.51 1.94 0.27 0.27 4.25E-03 0.27 3.90E-03
Previously accounted for Tank -----4.45E-04 -
Emergency Generator 0.42 0.09 0.03 0.03 1.63E-04 0.03 3.56E-04
Actual Tank -----1.11E-03 9.81E-05
Three Emergency Generators 0.47 0.10 3.32E-02 3.32E-02 1.83E-04 3.79E-02 4.00E-04
New Site Totals 8.46 1.93 0.26 0.26 4.23E-03 0.27 3.96E-03
Current Permitted PTE1 8.51 1.94 0.27 0.27 0.17 0.27 3.90E-03
Proposed Change in PTE -0.05 -0.01 -0.01 -0.01 -0.17 0.00 5.53E-05
Major Source Thresholds 100 100 100 70 70 70 25/10
Exceeding Major Source Thresholds?2,3 No No No No No No No
Modeling Thresholds4 40 -15 -40 -See HAPs Summary
Modeling Required?No No No No No No No
1. These emission totals represent the limit given in DAQE-AN0141260001-08
2. Major Source thresholds are defined by 40 CFR 51.165(a)(1)(iv)(A) and 40 CFR 52.21(b)(1)(i)(b)
3. Total HAP Threshold is stated in 40 CFR Section 63.2 under definition of a Major Source.
4. Modeling Limit is stated in UDAQ Emissions Impact Assessment Guidelines under Table 1: Total Controlled Emission Rates for New Sources.
Currently Permitted and to be Removed
Totals
Unit Group Potential Annual Emissions (tpy)
Currently Permitted Units
Proposed Units
Table 3. Diesel Storage Tank Emissions
Tank Capacity
(gal)Tank Location
Maximum
Potential
Throughput
(gal)1
VOC
Potential
Emissions
(lb/yr)2
VOC Potential
Emissions
(tpy)3
150 Aboveground 31,500 0.21 1.05E-04
150 Aboveground 31,500 0.21 1.05E-04
4,000 Underground 31,500 0.47 2.35E-04
8,000 Underground 35,010 2.23 1.11E-03
1. Facility-Wide Maximum Annual Fuel Consumption:
35,010 gal/yr
3. The maximum annual throughput for the 150-gallon and 4,000 gallon tanks is 31,500 gallons per year
and the maximum annual throughput for the 8,000 gallon tank is 35,010 gallons per year; therefore, the
total VOC emissions from all tanks is best represented by the the cooresponding maximum throughputs.
Previously accounted for Tank
Actual Tank
2. Source: EPA TANKS program emissions calculation summary for 150-gallon and 4,000 gallon tanks and Tank ESP
program emissions calculation summary for 8,000-gallon tank.
Table 4. HAPs Summary
Pollutant
Facility Total PTE
Before Project
(tpy)
Facility Total
PTE After
Project (tpy)
Change in Facility
Total PTE (tpy)
Change in Facility
Total PTE (lb/hr)
ETV1
(lb/hr)
Modeling
Required?
Acetaldehyde 1.40E-04 1.31E-04 -9.00E-06 -3.60E-05 6.94 No
Acrolein 2.83E-05 2.72E-05 -1.09E-06 -4.34E-06 --
Benzene 1.92E-03 1.91E-03 -8.62E-06 -3.45E-05 0.32 No
Formaldehyde 3.10E-04 2.96E-04 -1.38E-05 -5.54E-05 0.06 No
Toluene 7.03E-04 7.24E-04 2.15E-05 8.61E-05 14.92 No
Xylenes 4.83E-04 5.57E-04 7.35E-05 2.94E-04 --
1,3-Butadiene 4.13E-06 3.67E-06 -4.59E-07 -1.84E-06 0.29 No
Other HAPs 3.14E-04 3.17E-04 3.29E-06 1.32E-05 --
GeoCode: UT0930
Table 5. Maximum Long-term (Annual) Emergency Generator and Tank 1 HAPs Emission Rates
Source Fuel Type Engine Output
(kw)
Engine Output
(hp)
Heat Input
(MMBtu/hr)
Acetaldehyde
Emissions
(tpy)
Acrolein Emissions
(tpy)
Benzene Emissions
(tpy)
Formaldehyde
Emissions
(tpy)
Toluene
(tpy)1,3-Butadiene Xylenes
(tpy) (tpy)
EGEN1 Diesel 15 20.1 0.14 2.70E-05 3.26E-06 3.28E-05 4.15E-05 1.44E-05 1.38E-06 1.00E-05 2.99E-06
EGEN2 Diesel 15 20.1 0.14 2.70E-05 3.26E-06 3.28E-05 4.15E-05 1.44E-05 1.38E-06 1.00E-05 2.99E-06
EGEN3 Diesel 15 20.1 0.14 2.70E-05 3.26E-06 3.28E-05 4.15E-05 1.44E-05 1.38E-06 1.00E-05 2.99E-06
EGEN4 Diesel 500 670.5 4.69 2.96E-05 9.25E-06 9.11E-04 9.26E-05 3.30E-04 -2.26E-04 1.53E-04
EGEN5 Diesel 500 670.5 4.69 2.96E-05 9.25E-06 9.11E-04 9.26E-05 3.30E-04 -2.26E-04 1.53E-04
EGEN6 Diesel 40 53.6 0.38 7.20E-05 8.68E-06 8.76E-05 1.11E-04 3.84E-05 3.67E-06 2.68E-05 7.96E-06
Tank - 8,000 gal Diesel -----2.3E-06 -2.6E-05 -6.5E-05 4.3E-06
HAPs Emission Factors for Diesel Industrial Engines (< 600 hp).HAPs Emission Factors for Large Stationary Diesel Engines (> 600 hp).
Pollutant
Organic
Compound
Emission Factors
(lb/MMBtu)1
Pollutant
Organic
Compound
Emission Factors
(lb/MMBtu)1
Acetaldehyde 7.67E-04 Acetaldehyde 2.52E-05
Acrolein 9.25E-05 Acrolein 7.88E-06
Benzene 9.33E-04 Benzene 7.76E-04
Formaldehyde 1.18E-03 Formaldehyde 7.89E-05
Toluene 4.09E-04 Toluene 2.81E-04
Xylenes 2.85E-04 Xylenes 1.93E-04
1,3-Butadiene 3.91E-05 Other HAPs 1.30E-04
Other HAPs 8.48E-05
1. Emission factors taken from AP-42,
Chapter 3, Table 3.3-2
(Speciated Organic Compound
Emission Factors for Uncontrolled
Diesel Engines ).
1. Emission factors taken from AP-42,
Chapter 4, Table 3.4-3
(Speciated Organic Compound
Emission Factors for Uncontrolled
Diesel Engines ).
AT&T Communications of the Mountain States, Inc.

AT&T / NOI Application
Trinity Consultants C-1
APPENDIX C. SUPPORTING BACT INFORMATION
Cost Analyses
Table A-1. Control Cost Evaluation for Replacement Emergency Use Engine - General Information
Parameter Value Notes
Duty (kW)40
Duty (bhp)54 Approximate conversion from kW to hp is 1.341 hp/kW
Tier I Emission NOx Rate
(g/kW-hr)9.2 U.S. EPA Office of Transportation and Air Quality (U.S. EPA-420-B-16-022) published March 2016.
Tier I Emissions NOX (tpy)0.04 Total emission rate based on a maximum of 100 hr per year.
Tier III & Tier IV Emission NOx Rate
(g/kW-hr)4.70
U.S. EPA Office of Transportation and Air Quality (U.S. EPA-420-B-16-022) published March 2016. Emission
rate for NMHC+NOx was the published form, NMHC is anticipated to be a minor component of the
emission factor.
Tier IV Final Emissions NOX (tpy)0.02 Controlled emissions provided by Tier IV Final Nonroad Compression-Ignition Engines: Exhaust Emission
Standards for NOX.
Equipment Life Expectancy (Years)15 Exemption to replacement engine provisions codified in 40 CFR 60.4210(i)
Interest Rate (%) 7.00%OMB Circular A-4, https://obamawhitehouse.archives.gov/omb/circulars_a004_a-4/
Table A-2. Control Cost Evaluation for Replacement Emergency Use Engine - Capital Investment
Parameter Value Notes
Total Capital Investment ($)$19,000 Cost estimate from a reliable vendor for a replacement 30 kW engine. Cost in 2023 dollars.
Capital Recovery Factor (CRF) 0.1098
U.S. EPA Cost Control Manual Section 1, Chapter 2 Cost Estimation: Concepts and Methodology, Equation
2.8a
Capital Recovery Cost (CRC) $2,086
U.S. EPA Cost Control Manual Section 1, Chapter 2 Cost Estimation: Concepts and Methodology, Equation
2.8
Process Information
Economic Factors
University of Utah Trinity Consultants
Cost Analyses
Table A-3. Control Cost Evaluation for Replacement Emergency Use Engine - Annual Operating Costs
Parameter Value Notes
Operating Labor, Maintenance,
Brake Specific Fuel Consumption,
and Catalyst Maintenance
$4
$/hp, U.S. EPA Alternative Control Techniques Document: Stationary Diesel Engines (U.S. EPA Contract
No. EP-D-07-019) Published March 5, 2010, Cost values are cited to be from 2005 and have been lowered
to match a run time of 100 hours.
Inflation Factor 1.69 Based on U.S. Bureau of Labor Statistics CPI Inflation Calculator from January of 2003 to December of
2023. https://www.bls.gov/data/inflation_calculator.htm
Total Direct Operating Costs $363
Table A-4. BACT Control Cost Evaluation for Replacement Emergency Use Engine - Annual Operating, Insurance, Tax, and Other Costs
Parameter Value Notes
Total Annual Cost $2,449 Sum of Capital Recovery Cost, Total Direct Operating Costs, Insurance, Tax and Other Annual Costs.
NOX Removed (tpy)0.02
Cost per Ton of NOX Removed
($/ton)$123,413
Direct Operating Costs
NOX Cost Per Ton Removed
University of Utah Trinity Consultants
UTAH DIVISION OF AIR QUALITY —NOTICE
OF INTENT
•AT&T Communications of the Mountain States —
•Brigham City,Utah
AT&T
Prepared by:
TRINITY CONSULTANTS
4525 Wasatch Boulevard
Suite 200
Salt Lake City,Utah 84104
[phone]
January 2024
Trinyj
Consulta
TABLE OF CONTENTS
1.EXECUTIVE SUMMARY 1-1
2.GENERAL INFORMATION 2-1
2.1 Source Identification Summary 2-1
2.2 Area Designation 2-1
2.3 Source Size Determination 2-1
2.4 Notice of Intent Forms 2-2
2.5 Notice of Intent Fees 2-2
3.DESCRIPTION OF PROJECT 3-1
3.1 Description of Project 3-1
3.2 Site Plan 3-1
4.EMISSION RELATED INFORMATION 4-1
4.1 Diesel-Fired Emergency Generators 4-1
4.2 Organic Uquid Storage Tank 4-2
5.BEST AVAILABLE CONTROL TECHNOLOGY (BACT)ANALYSIS 5-3
5.1 Emergency Generator 5-3
51.1 Diesel-Fired Engine Step 1-Identify Potential Control Technologies 5-3
5.1.2 Diesel-Fired Engines Step 2—Ellminate Technically Infeasible Options 5-4
11.3 Diesel-Fired Engines Step 3—Ranking of Remaining Control Technologies by Control
Effectiveness 5-5
5.1.4 Diesel-Fired Engine Step 4—Evaluate Most Effective Controls and Document Results ..
51.5 Diesel-Fired Engine Steps-Select BACT 5-6
5.2 Organic Liquid Storage Tank 5-6
5.2.1 Organic Liquid Storage Tank Step 1-Identify Potential Control Technologies 5-6
5.2.2 Diesel-Fired Engines Steps 2-4 5-6
5.2.3 Diesel-Fired Engine Steps 5-7
6.EMISSION IMPACT ANALYSIS 6-1
7.EMISSION IMPACT ANALYSIS 7-1
7.1 Offset Applicability 7-1
71.1 PMzs Offsets 7-1
8.REGULATORY ANALYSIS 8-1
8.1 UDAQ Air Quality Rules 8-1.
&1.1 LIAC R307-1O1 General Requirements:8-4
8.1.2 UAC R307-107 General Requirements:Breakdowns 8-5
8.1.3 UAC R307-165 Stack Testing Error!Bookmark not defined.
&1.4 IJAC R307-201 Emission Standards:General Emission Standards 8-5
&1.5 UAC R307-203 Emission Standards:Sulfur Content of Fuels 8-5
&1.6 UAC R307-309 Nonattainment and Maintenance Areas for PMJO and PM2.5:Fugitive
Emissions and Fugitive Dust 8-5
&1.7 UAC R307-401-8 Permits:Permit New and Modified Sources —Approval Order:8-5
8.1.8 UAC R307-414 Permits:Fees for Approval Orders:8-6
8.2 Federal Rules:National Emission Standards for Hazardous Air Pollutants 8-6
AT&T I NOl Application
Trinity Consultants
8.21 SubpartA —Gena/Provisions .8-6
8.2.2 Subpart ZW —Stationary Reciprocating Internal Combustion Engifles .8-7
8.3 Federal Rules:New Source Performance Standards 8-7
&3.1 Subpart A -General Pro visions 8-7
8.3.2 NSPS Subpart 1111—Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines 8-7
APPENDIX A.FORMS A-i
APPENDIX B.EMISSIONS CALCULATION B-i
APPENDIX C.SUPPORTING BACT INFORMATION C-i
AT&T I NOT Application
Trinity Consultants ii
1.EXECUTIVE SUMMARY
AT&T Communications of the Mountain States (AT&T)operates a data center (the Facility)located at 1760
North Highway 38 in Brigham City,Box Elder County,Utah,with air emissions primarily due to the operation
of emergency generators.Box Elder County is an attainment area of the National Ambient Air Quality
Standards (NAAQS)for all pollutants with exception to PM2.s for which it is classified as serious nonattainment.
The Facility currently operates under Utah Approval Order (AO)DAQE-AN0141260001-08.
AT&T is proposing to make the following changes to the Facility:
Remove three (3)15 kW emergency generators (ID:EGEN:1-3);
Add one (1)40 kW emergency generator;and
Update the representation of the diesel storage tank (ID:TANK 1)from 4,000 gallons to 8,000 gallons.
The facilities will be subject to New Source Performance Standards (NSPS)40 Code of Federal Regulations
(CFR)60 Subpart A (General Provisions),NSPS 40 CFR 60 Subpart 1111 (Standards of Performance for
Stationary Compression Ignition Internal Combustion Engines),National Emissions Standards for Hazardous
Air Pollutants (NESHAP)63 Subpart A (General Provisions),NESHAP 63 Subpart ZZZZ (Stationary
Reciprocating Internal Combustion Engines).
This NOl air quality application is being submitted in accordance with the Utah Division of Air Quality (UDAQ)
rules,Utah Administrative Code (UAC)R307-401,and includes all supporting documentation in order to modify
DAQE-AN0141260001-08 and obtain authorization for the changes specified above.Appendix B summarizes
the emissions resulting from the Facility after the proposed changes.This NOl includes the following:
NOT Air Permit Application Forms and Fees;
s Process Description;
Potential to Emit (PTE)Calculations;
Best Available Control Technology (BACT)Analysis;and,
Applicable Requirements.
AT&T!NOl Application
Trinity consultants i-i
2.GENERAL INFORMATION
The following section contains the information requested under the “Source Identification Information”section
of UDAQ’s Form I Notice of Intent (NOl)Application Checklist.
2.1.Source Identification Summary
Institution Name:AT&T Communications of the Mountain States,Inc.
Address:1760 North Highway 38,Brigham City,UT 84302-3711
County:Box Elder County
UTM Coordinates:4,599,323 meters N,415,463 meters E,Zone 12
Primary SIC Code:4813 —Telephone Communications,except Radiotelephone
Soure njuination:NonattaA,c1s
All correspondence regarding this submission should be addressed to:
Julianne Barnum
AT&T Communications of the Mountain States,Inc.
Area Manager EHS
1311 S.Akard 5•,l2 Floor
Dallas,TX 75202
Phone:[phone]
Email:G43913©att.com
2.2 Area Designation
AT&T is located within an area of Box Elder County that is classified as in attainment for all pollutants with
exception to PM2.s for which it is classified as serious nonattainment area of the National Ambient Air Quality
Standards (NMQS).
2.3 Source Size Determination
As presented in Appendix B,site-wide emissions at the Facility are less than the Major Source Thresholds
(MST)for all criteria pollutants.Therefore,the Facility is classified as a minor source.
AT&T!NOl Application
Trinity consultants 2-1
2.4 Notice of Intent Forms
The following UDAQ forms have been included with this NOl air permit application:
•Form 1 —Notice of Intent (NOl)Application Checklist;
•Form 2 —Company Information/Notice of Intent (NOfl;
•Form 4—Project Information;
•Form 5 —Emissions Information Criteria/GHGs/HAPs;
•Form 17 —Diesel Powered Standby Generator;and
•Form 20 —Organic Liquid Storage Tank.
2.5 Notice of Intent Fees
AT&T will use the UDAQ’s Payment Portal to prepay the following UDAQ NOl air permit application fees
associated with this submittal:
“Application Filing Fee”for the “New Minor Source or Minor Modification at Minor or Major Source”category
=$500;and
“Application Review Fee”for the “New Minor Source or Minor Modification at Minor or Major Source”category
in maintenance or non-attainment areas =$2,300.
Total UDAQ fees =$2,800.
AT&T understands that the total permit review fee is based on the total actual time spent by UDAQ staff
processing this NOI air permit application.Upon issuance of the AO,if the total review time is more than 20
standard hours,UDAQ will invoice AT&T at $115 per hour for the additional time above 20 standard hours.
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3.DESCRIPTION OF PROJECT
3.1 Description of Project
AT&T currently operates emergency generators at the data center for electricity production only during periodswhenelectricpowerfrompublicutilitiesisinterrupted,or for regular maintenance of the generators.In June2016,AT&T replaced three (3)existing is kW generators with one (1)40kW generator.AT&T is nowrequestingthatthischangebereflectedinitsAO.Associated with the change in generators,AT&T is alsoupdatingthevolumeofDieselTankito8,000 gallons which was previously permitted at 4,000 gallons.Thechangesaresummarizedbelow:
Remove three (3)i5 kW emergency generators (ID:ECEN:i-3);
Add one (1)40 kW emergency generator;and
Update the representation of the diesel storage tank (ID:TANK i)from 4,000 gallons to 8,000 gallons.
Figure 3-1 shows the location of the Facility.
3.2 Site Plan
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Figure 3-1.Location of AT&T Data center
3-1
4.EMISSION RELATED INFORMATION
This section details the methodology used to calculate controlled and uncontrolled emissions for criteria
pollutants and Hazardous Air Pollutants (HAPs)associated with each new unit and its associated fugitives as
regulated by R307-401-5(2)(b).Detailed emission calculation tables are included in Appendix B.Additionally,
a comparison to major source thresholds is conducted.
4.1 Diesel-Fired Emergency Generators
Emission calculations were performed for both the emergency generators to be removed and the proposed
emergency generator with a proposed cap of 100 hours of operation per year per generator,inclusive of
testing and maintenance.Calculations for each of the criteria pollutants are based on the annual hours of
operation at the maximum power output of the engine.Emission factors (EF)for diesel-fired operation were
obtained from the Environmental Protection Agency (EPA)AP 42,Volume I,Fifth Edition,Table 3.3-1.
The following calculations were carried out for each generator for NOx,CC,PMio,PM2.s,502,and Volatile
Organic Compounds (VOCs).
lbs hrsAnnualEmissionRate(tpy)=Emission Factor
(hh)
x Power Output [hp]x Hours olOperation (—)x
1 ton
Conversion
(2000 Ibs)
The proposed emergency engine will be using ultra-low sulfur diesel (ULSD)fuel.The emission factor for SOz
is based on a fuel sulfur content of 0.0015%for ultra-low sulfur diesel fuel,as defined under 40 CFR 80,
Subpart I,Section 80.510(c)(l).The 502 emission factor from AP 42,Section 3.3 Table 3.3-1 is used in the
emission calculations and accounts for the fuel sulfur content SO2 hourly emissions are calculated using the
following equation.
lbs lbs502HourlyEmissionRate(-fl—)=Emission Factor
(hP-hi
x Power Output [hp]
lbs hrs502AnnualEmissionRate(tpy)=Hourly Emissions (-—-)x Hours of Operation
1 ton
x Conversion
(2000 Ibs)
HAP emissions were determined using the maximum heat input and annual hours of operation.Emission
factors for HAP5 are obtained from AP-42,Section 3.3,Table 3.3-2.
HAP Annual Emission Rate (tpy)
lbs MMBtu hrs tons=Emission Factor
(MMBtu)x Heat Input (hr )xHours of Operation (—)x
(2000 lID)
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4.2 Organic Liquid Storage Tank
Emission calculations were performed to quantify the emissions implications of increasing the represented
volume of the diesel storage tank from 4,000 gal to 8,000 gal.Tank HAP and VOC emissions were caiculated
based on an unchanged maximum annual throughput of 31,500 gallons per year using the EPA approved
TankESP software which is based on AP-42 Section 7.1,Uquid Storage Tanks (June 2020).See the emission
calculations and the TankESP output in Appendix B for further details.
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5.BEST AVAILABLE CONTROL TECHNOLOGY (BACT)ANALYSIS
In the State of Utah,under R307-401-5(2)(d),Notice of Intent,every facility,operation,or process thatproposesanyactivitythatwouldemitanaircontaminantintotheair,must consider BACT for a proposed new
source or modification.1 The below BACT analysis only addresses units which will be modified,installed,or
otherwise addressed in this NOl.
5.1 Emergency Generator
5.1.1 Diesel-Fired Engine Step 1-Identify Potential Control Technologies
The least stringent emission rate allowable for BACT is any applicable limit under either New Source
Performance Standards (NSPS —Part 60,)or National Emission Standards for Hazardous Air Pollutants
(NESHAP —Part 63).Emission limits for diesel-fired engines are limited by EPA’S Tier program established in
40 CER 1039,and are referenced by NSPS Subpart 1111,Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines.2 Under these regulations EPA requires manufacturers to reduce the
emissions from engines produced after certain dates in a tiered fashion,based on the size and model year.
In general,the higher the tier rating,the lower the emissions produced.
The proposed unit is 40kW and meets Tier 1 emission standards for all pollutants.It is the manufacturer’s
responsibility to ensure that these units meet the established emission limitations or Tier rating.In order toensuretheseemissionlimitationsaremetmanufacturersoftenincorporatedesignelements,such asturbochargers,aftercoolers,positive crankcase ventilation,and high-pressure fuel injection.The incorporation
of these design elements allows the units to met minimum BACT standards and are therefore not further
considered in this analysis.
In order to identify additional control technologies applied to emergency use engines the following sources
were reviewed:
•EPA’s RBLC Database for Diesel Generators (process type 17.210 Small Internal Combustion Engines
[<500 Hp]burning Fuel Oil);3
•EPA’s Air Pollution Technology Fact Sheets;
•SCAQMD Example Permits;
•TCEQ’s BACT combustion workbook;and
•BMQMD Nonroad BACT Assessments.
The following control methods have been identified as potentially feasible for control of emissions from
emergency generator engines:
•Limited Hours of Operation;
•Good Combustion Practices (GCP);
•Exhaust Gas Recirculation (EGR);
•Use of Ultra-Low Sulfur Fuel;
UAC R307-401-4
2 Non-Emergency regulated per 40 CFR 60.4201,Emergency regulated by 40 CFR 60.4202,and General Requirementsregulatedper40CFR604203.
Database accessed January 30,2024.
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•Diesel Particulate Filter (DPF);
•Diesel Oxidation Catalyst (DOC);and
•Selective Catalyst Reduction (5CR).
5.1.2 Diesel-Fired Engines Step 2 —Eliminate Technically Infeasible Options
Limited Hours of Opeiation
One of the options to control the emissions of all pollutants released from emergency generator engines is tolimitthehoursofoperationfortheequipment.Due to the designation of this equipment as emergencyequipment,only 100 hours of operation for maintenance and testing are permitted per NSPS Subpart 1111.
Therefore,limiting hours of operation is considered technically feasible.
Good Combustion Practices
GCP refers to the operation of engines at high combustion efficiency,which reduces the products of incompletecombustion,such as VOC and CO.Emergency generator engines are designed to achieve high combustion
efficiency when maintained and operated according to the manufacturer’s written instructions.GCP areconsideredtechnicallyfeasible.
Exhaust Gas Recirculation
NO reduction can be achieved through recirculating exhaust into the engine.EPA tests have demonstrated
NOx reduction up to 50 percent if the engine timing is retarded,but test results are accompanied by anincreaseinparticulates.4 Computer based control schemes can assist in NOx reduction with associated timingretardation,but EGR can also result in heat rejection,reduced power density,and lower fuel economy.Exhaust
gas recirculation is considered technically infeasible.
Diesel Particulate Filters
This simple technology is placed in the exhaust pathway to prevent the release of particulate and may becoatedwithacatalysttofurthercapturehydrocarbonemissions.According to EPA’s Response to Public
Comments on Notice of Reconsideration of NESHAP for RICE and NSPS for Stationary ICE,“Diesel particulate
filters are also proven,commercially available technology...and are capable of reducing diesel PM by gopercentormore.”5 Additionally,the California Air Resources Board (CARB)was able to determine that thistechnologywastechnicallyfeasibleforemergencyandprimeenginesthroughobtainingseveralvendorquotes.6 This technology is considered technically feasible.
Diesel Oxidation Catalyst
A DOC utilizes a catalyst such as platinum or palladium to oxidize VOC emissions in the engine’s exhaust tocarbondioxide(CO2)and water.Use of a DOC can result in approximately 90 percent reduction in VOC
4us.EPA control of Heavy-Duty Diesel NOX Emissions by Exhaust gas recirculation,Office of Mobile Source Air PollutionEmissionscontrolTechnologyDMsion,August 1985
Response to Public comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants forStationaryReciprocatingInternalcombustionEnginesandNewSourcePerformanceStandardsforStationaryInternalCombustionEngines,EPA Docket EPA-HQ-OAR-2008-0708,June 16,2014
6 Response to Public Comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants forStationaryReciprocatingInternalcombustionEnginesandNewSourcePerformanceStandardsforStationaryInternalCombustionEngines,EPA Docket EPA-HQ-OAR-200S-0708,June 16,2014
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emissions.7 In addition to controlling VOC,a DOC also has the potential to reduce PM emissions by 30 percent(based on the concentration of soluble organics).6 However,the full reduction potential requires a minimum
operating temperature of 150°C (300 °F).9 Similarly,U.S.EPA recommends if an engine emits extremely highlevelsofPMand/or idles for long periods of time,an exhaust backpressure monitoring and operatornotificationsystemmaybeinstalledtonotifytheoperatorwhenmaintenanceisneeded.’°For this reason,
DOC control efficiencies are expected to be relatively low during the first 20 -30 minutes after engine startup,in fact U.S.EPA considered this method of aftertreatment to be generally unsuitable for backup use.’1SinceoperationofemergencyenginestypicallyonlyincludesshortdurationrunsandAT&T does not requiretheenginetobebroughttofullloadformonthlymaintenanceandtesting,DOC is considered technicallyineffectiveformaintenanceandtesting.t2
Selective Catalytic Reduction
SCR systems introduce a liquid reducing agent such as ammonia or urea into an engine’s flue-gas stream priortoacatalyst.The catalyst reduces the temperature needed to initiate the reaction between the reducing agent
and NOx to form nitrogen and water.Additional variations including non-selective catalytic reduction (NSCR)
and selective non-catalytic reduction (SNCR)may be used but are not considered standard industry practiceandarenotlistedintheRBLC,thus SCR remains the focus of this technical analysis.
For SCR systems to function effectively,exhaust temperatures must be high enough (480 °F to 800 99 toenablecatalystactivation,which will be accounted for in operation.13 For this reason,SCR control efficiencies
are expected to be relatively low during the first 20 -30 minutes after engine start up.Since operation ofemergencyenginestypicallyonlyincludesshortdurationrunsformaintenanceandtesting,SCR is consideredtechnicallyineffectiveformaintenanceandtesting.
5.1.3 Diesel-Fired Engines Step 3—Ranking of Remaining Control Technologies
by Control Effectiveness
Effective control technologies for diesel engines are listed in the following table:
‘US.EPA,Alternative Control Techniques Document:Stationary Diesel Engines,March 5,2010,p.41.
Response to Public comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants forStationaryReciprocatingInternalcombustionEnginesandNewSourcePerformanceStandardsforStationaryInternalcombustionEngines,EPA Docket EPA-HQ-OAR-2008-0708,June 16,2014
U.S.EPNs Technical Bulletin for Diesel Oxidation Catalyst Installation,Operation,and Maintenance,EPA-42o-F-10-030publishedinMay2010.
‘°Ibid.
“Response to Public comments on Notice of Reconsideration of National Emission Standards for Hazardous Air Pollutants forStationaryReciprocatingInternalcombustionEnginesandNewSourcePerformanceStandardsforStationaryInternalcombustionEngines,EPA Docket LPA-HQ-OAR-2008-0708,Page 85,June 16,201412Annualtestingrequirestheenginesbeingbroughttofullload,but this is a small percentage of the overall maintenance andtestingoperationtime.
13 EPA Air Pollution control Technology Fact Sheet for Selective catalytic Reduction (SCR),EPA-452/F-03-032
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Table 5-1 Emergency Engine Controls Feasibility
Technically
Control Feasible?
____________
(Yes/No)
Limited Hours of Qi
GCP
EGR
DPF
DOC
5CR
The engine proposed meet the NSPS standards.Additionally,all units proposed will operate for limited hours,using good combustion practices,diesel particulate filters,and fueled by ultra-low sulfur diesel.
5.1.4 Diesel-Fired Engine Step 4—Evaluate Most Effective Controls and Document
Results
In order to ensure a complete analysis is presented AT&T has conducted a cost analysis for a new replacement
30kW engine that would meet the most current Tier IV standards.This cost analysis focused on NOx as thereductionpotentialforthispollutantisgreaterthanallothercriteriapollutants.Based on a cost estimate from
a reliable vendor,the approximate total capital investment of a new 30kW engine is $19,000.Further,basedonU.S.EPA’s Alternative Control Techniques Document:Stationary Diesel Engines,the approximate operatinglabor,maintenance,brake specific fuel consumption,and catalyst cost is $4 per horsepower.’4 Afterconsideringeconomicfactorsandotherannualcoststhecalculatedcostpertonremovedis$123,413 per tonremoved.AT&T proposes that this is not cost effective and was not further considered.A full cost analysis isincludedinAppendixC.
5.1.5 Diesel-Fired Engine Step 5 —Select BACT
AT&T uses all technically and economically feasible controls which generally include engine design consistentwithNSPS1111(post-2006),EPA Tier rating,DPF,limited hours of operation,good combustion practices and/or
use of ultra-low sulfur fuel.Exact emission rates,reflecting this BACT,are included in the emission calculations.
5.2 Organic Liquid Storage Tank
5.2.1 Organic Liquid Storage Tank Step 1-Identify Potential Control Technologies
Emissions from fixed roof storage tanks result from displacement of headspace vapor during filling operations
(working losses)and from diurnal temperature and heating variations (breathing losses).AT&T reviewed avarietyofavailablesources,including but not limited to the RBLC.The identified control methods for tanks ofthissizeandvaporpressureincludedgoodoperatingandmaintenancepracticesandsubmergedfilling.
14 EPA contract No.EP-D-07-019,Published March 5,2010
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according to the manufacturer’s written instructions.Good operating and maintenance practices areconsideredtechnicallyfeasible.
As this tank is buried underground,minimal temperature changes are to be expected.Additionally,as thedieselfuelisusedonlyinthecaseofanemergency,it is a low throughput tank and therefore alreadyminimizesthefrequencyoffillingandtheassociatedemissions.AT&T uses good operating and maintenance
on the diesel tank.
Submerged Filling
During submerged loading,the fill pipe opening is below the liquid surface level and liquid turbulence iscontrolledsignificantly,resulting in much lower vapor generation than encountered during splash loading.15
While technically feasible,due to the very low emission rate,it has been assumed that the retrofit of thistechnologywillbeeconomicallyinfeasible.
5.2.3 Diesel-Fired Engine Step S
AT&T proposes good operating and maintenance practices meets BAa.
‘EPA AP-42 Section 5.2 Transportation and Marketing of Petroleum Liquids
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6.EMISSION IMPACT ANALYSIS
Table 6-1 compares criteria pollutant total proposed emissions to applicable modeling thresholds contained in R307-41J3-4 through 7,andR307-410-4.
Table 6-1..Facility-Wide Emissions and Comparison to Major Source and Modeling Thresholds.
087*n8V Pfld thin
Emeigency Eenerutorl 8.10 1.88 32S 025 0.14 026 3.930-03PreviouslyaccounTedtonrank
-
-]--
-4.450-04 -
——
Orel5nocv Generator 3A2 I 0.09 I o.c3 303 CII 0.03 334€-Is-Actual Turk
---I .
.1210-03 931E-3S
0anayPmd aad —w.d
Emrrc’xy Gnn,ats 0.1€012 l.11E-I 1.120-01 3.030-03 1.28002 ,001E-O4ETcbh
[Pi.wsRsTolals 5,45 1.93 026 825 0,14 J..p.27 3,yho•rlCwrr.nt P.rmle.d prE’831 1,94 027 027 0,17 027 3.000-03fij.d 0.111(8 in pot -0.05 -0.01 --‘0,01 -3.03 -0.33 0.00 5,530-08
:!
Maior Sooner Thresholds ,100 100 100 70 70 70 25/Ia
ExceedlMu00iSoorceThnesl10ldA?’NO No No__NO NO No NO
Mode0Thria1dc ‘15 -See H Sumarj810400Rea’r,a?No No No Nc’No No NoIv.These.fl4sIon Ovals rePOesenllOe reid a.sn in DAQE-800141380301’Ou
LwuiorSrozcn lhreshoI,at defised by ficrfl 5’.ta0’tioOD:anT 80 CFfl 5Z28br0851
3,lasni ,NtPThrr-sknoin,iaIrdinu0000seolsentL’uvdei ueooiiirsofaooajoisouice.
801dm8 Limo slaved fl 0060 Oflinsioss dean Asoessnwui tilelinDs anne,is kle I Total cenI,olled Eminsion Raves ID,New snore,.
Table 6-1..Facility-Wide HAP Emissions and Comparison to Modeling Thresholds
T OH.Jt1
A001800ehyole I 400-04 1 310-04 ‘°°-O -3 °I NoA000Ovini2036-05 2 72E-05._j -1 006-05 -4 346-06
-
Senzene I 920-03 1 91E-03 j -3 626-06 -3 45E-05 032 NoFormaldehyde3100-04 2 966.04 -1 380-05 -5540-05 0.06 No
Toluene 7.030-04 7 246-04 -2 156-05 8 610-05 14.92 NoXyleoTes4.836-04 5 576-04 350-05 2.946-04 -
I.3-8osiene 4 13t-t6 3 &7E-06 -4591.07 -1 84E-06 0 .NoOtherNtAPs314E-04 3 liE-Cd 3 206-06 I I 320-05 i -
-
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7.EMISSION IMPACT ANALYSIS
7.1 Offset Applicability
7.1.1 PM2.5 Offsets
PM2.s offsets are applicable for major modifications of sources located within or impacting a PM2.snonattainmentareaoftheNAAQS.A major modification in a serious nonattainment area is defined in R307-403-S(2)(c)as “a rate of emissions that would equal or exceed 10 tons per year (tpy)of direct PM2.s,40 tpyofsulfurdioxide,40 tpy of nitrogen oxides,or 40 tpy of volatile organic compounds (VOC)”.The proposedmodificationsdonotexceedthelimitsofPM2s,SO2,NOx,or VOCs.AT&T is therefore not subject to the offsetrequirementsofR307-403.
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8.REGULATORY ANALYSIS
8.1 UDAQ Air Quality Rules
AT&T has evaluated the applicability of each rule under the Utah Administrative Code (UAC)Title R307.RulesgenerallyapplicabletoAT&T but not affected by this project have not been addressed.
Table 8-1.Evaluation of UDAQ Air Quality Rules
Reference Regulation Name Applicability
Yes No
R307-1O1 General Requirements X
‘General Requirements:Broadly ApplicableR307-102 xRequirements
R307-103 1 Administrative Procedures X
R307-104 2 Conflict of Interest X
R307-105 1 General Requirements:Emergency controls X
R307-107 General Requirements:Breakdowns X
1 General Requirements:State ImplementationR307-11O xPlan
R307-115 ‘General Conformity X
General Requirements:Tax Exemption for AirR307-t20 XPollution_Control_Equipment
General Requirements:Clean Air and EfficientR307-121 XVehicleTaxCredit
General Requirements:Heavy Duty Vehicle TaxR307-122 Credit
General Requirements:Clean Fuels and VehicleR307-123 XTechnologyGrantandLoanProgram
General Requirements:Conversion to AlternativeR307-124 XFuelGrant_Program
Clean Air Retrofit,Replacement,and Off-RoadR307-125 XTechnology_Program
R307-130 General Penalty Policy X
Enforcement Policy for Asbestos HazardR307-135 XEmergency_Response_Act
R307-15O Emission Inventories X
R307-165 Stack Testing X
R307-170 Continuous Emission Monitoring Program X
R307-201 [mission Standards:General Emission Standards X
R307-202 Emission Standards:General Burning X
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Reference Regulation Name Applicability
Yes No
R307-203 Emission Standards:Sulfur Content of Fuels X
R307-204 Emission Standards:Smoke Management X
Emission Standards:Fugitive Emissions andR307-205 xFugitive_Dust
R307-206 Emission Standards:Abrasive Blasting X
Residential Fireplaces and Solid Fuel BurningR307-207 XDevices
R307-208 Outdoor Wood Boilers X
‘Standards of Performance for New StationaryR307-210 XSources
‘National Emission Standards for Hazardous AirR307-214 XPollutants
R307-220 Emission Standards:Plan for Designated Facilities X
Emission Standards:Emission Controls forR307-221 XExisting_Municipal_Solid_Waste_Landfills
Emission Standards:Existing Incinerators forR307-222 xHospital,Medical,Infectious Waste
Emission Standards:Existing Small Municipal xR307-223 Waste Combustion Units
R307-224 Mercury Emission Standards:Coal Fired Electric xGenerating_Units
NOx Emission Limits for Natural Gas-Fired WaterR307-230 XHeaters
R307-240 Prescribed Burning X
R307-250 Western Backstop Sulfur Dioxide Trading Program X
Utah and Weber Counties:Oxygenated GasolineR307-301 XProgram_as a_Contingency_Measure
R307-302 Solid Fuel Burning Devices X
R307-303 Commercial Cooking X
R307-304 Solvent Cleaning X
Nonattainment and Maintenance Areas for PM10:R307-305 XEmissionStandards
PMjo Nonattainment and Maintenance Areas:R307-306 xAbrasive_Blasting
R307-307 Road Salting and Sanding X
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Reference Regulation Name Applicability
Yes No
Nonattainment and Maintenance Areas for PMioR307-309 and PM2s:Fugitive Emissions and Fugitive Dust
Salt Lake County:Trading of Emission BudgetsR307-310 for Transportation Conformity
R307-311 Utah County:Trading of Emission Budgets for
____________
Transportation Conformity
R307-312 Aggregate Processing Operations for PM2.s
Nonattainment Areas
NO Emission Controls for NaturalR307-315
____________
Boilers 2.0-5.0 MMBtu
NO Emission Controls for NaturalR307-316
____________
Boilers Greater than 5.0 MMBtu
Ozone Maintenance Areas and Ogden City:R307-320
_____________
Employer Based Trip Reduction Program
Ozone Nonattainment and Maintenance Areas:R307-325 General Requirements
Ozone Nonattainment and Maintenance Areas:
R307-326 Control of Hydrocarbon Emissions in Petroleum
Refineries
Ozone Nonattainment and Maintenance Areas:R307-327
______________
Petroleum Liquid Storage
R307-328 Gasoline Transfer and Storage
R307-335 Degreasing
Ozone Nonattainment and Maintenance Areas:R307-341
______________
Cutback Asphalt
R307-342 Adhesives and Sealants
R307-343 Wood Furniture Manufacturing Operations
R307-344 Paper,Film,and Foil Coatings
R307-345 Fabric and Vinyl Coatings
R307-346 Metal Furniture Surface Coatings
R307-347 Large Applicable Surface Coatings
R307-348 Magnet Wire Coatings
R307-349 Flat Wood Panel Coatings
R307-350 Miscellaneous Metal Parts and Products Coatings
R307-351 Graphic Arts
R307-352 Metal Container,Closure,and Coil Coatings
R307-353 Plastic Parts Coatings
R307-354 Automotive Refinishing Coatings
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Gas-Fired
Gas-Fired
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ApplicabilityReferenceRegulationName
Yes No
R307-355 Aerospace Manufacture and Rework Facilities X
R307-356 Appliance Pilot Light X
R307-357 Consumer Products X
R307-361 Architectural Coatings X
R307-401 1 Permit:New and Modified Sources X
1 Permits:New and Modified Sources inR307-403 XNonattainmentandMaintenanceAreas
Permits:Major Sources in Attainment orR307-405 XUnclassifiedAreas(P50)
R307-406 2 Visibility X
R307-410 Emissions Impact Analysis X
R307-414 Fees for Approval Orders X
R307-415 1 Permits:Operating Permit Requirements X
R307-417 Acid Rain Sources X
Permits:Ozone Offset Requirements in Davis andR307-420 XSalt_Lake_County_Counties
Permits:PM10 Offset Requirements in Salt LakeR307-421 XCounty_and_Utah_County
R307-424 Mercury Requirements for Electric Generating
Units
R307-5O1 to Oil and Gas Industry X511
R307-801 Utah Asbestos Rule X
Lead-Based Paint Program Purpose,Applicability,R307-840 Xand_Definitions
Residential Property and Child-Occupied FacilityR307-841 XRenovation
R307-842 Lead-Based Paint Activities X
1.The subject rule is or could be applicable to AT&T;however,this rule is not specific to operationalcompliancerequirementsandisthereforenotdiscussedinthisNOlairpermitapplication.
2.At the time of submission of this Nd air permit application,this rule does not apply.
3.Applicable NSP5 and NESHAP regulations are detailed under appropriate project headings.
8.1.1 UAC R307-1O1 General Requirements:
Chapter 19-2 and the rules adopted by the Air Quality Board constitute the basis for control of air pollutionsourcesinthestate.These rules apply and will be enforced throughout the state and are recommended foradoptioninlocaljurisdictionswhereenvironmentalspecialistsareavailabletocooperateinimplementingrulerequirements.
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NA4QS,NSPS,National Prevention of Significant Deterioration of Air Quality (PSD)standards,and theNESHAPapplythroughoutthenationandarelegallyenforceableinUtah.
AT&T will comply and conform to the definitions,terms,abbreviations,and references used in the R307-101
and 40 CER.
8.1.2 UAC R307-107 General Requirements:Breakdowns
AT&T will report breakdowns within 24 hours via telephone,electronic mail,fax,or other similar method andprovidedetailedwrittendescriptionwithin14daysoftheonsetoftheincidenttoUDAQ.Breakdown reportswillincludeallreportingdetailsoutlinedinR307-107-2,including,but not limited to,the cause and nature oftheevent,estimated quantity of emissions,and time of emissions.
8.1.3 IJAC R307-201 Emission Standards:General Emission Standards
All rules applicable to AT&T are incorporated by reference from 40 (YR Part 60.Applicability and requirements
for these rules are outlined in Section 8.2 of this submittal.
8.1.4 UAC R307-203 Emission Standards:Sulfur Content of Fuels
Sulfur emissions shall be no more than 0.85 pounds sulfur per million gross BTU heat input for any oil.The
following specifications for each purchase of fuel oil are recorded:weight percent sulfur,gross heating value
(Btu per unit volume),and density.These parameters shall be determined in accordance with the methods of
the American Society for Testing and Materials (ASTM).Records of fuel sulfur content shall be kept for all
periods when the Facility is in operation and shall be made available to the Director upon request and shall
include a period of two years ending with the date of the request.
AT&T will record the following specifications for each purchase of fuel oil in the event that it will be used:
weight percent sulfur,gross heating value (Btu per unit volume),and density.In doing so,AT&T will meet
the emission standards for sulfur content of fuel as described in R307-203-1.(1)(a).
8.1.5 UAC R307-309 Nonattainment and Maintenance Areas for PM10 and PM2s:
Fugitive Emissions and Fugitive Dust
AT&T is expected to be a fugitive source of PM1D emissions and is located in an area of PMio nonattainment.
Therefore,AT&T will comply with any requirements that are issued in its AO limiting opacity of fugitive
emissions and requiring opacity observations as specified in R307-309-4.
8.1.6 UAC R307-401-8 Permits:Permit New and Modified Sources —Approval
Order:
(1)The director will issue an AO if all conditions and regulations have been met.
(a)The degree of pollution control for emissions,to include fugitive emissions arid fugitive
dust,is at least best available control technology.When determining best available control
technology for a new or modified source in an ozone nonattainment or maintenance area that
will emit VOC or NOx,best available control technology shall be at least as stringent as anyControlTechniqueGuidancedocumentthathasbeenpublishedbyEPAthatisapplicableto
the source.
(b)The proposed installation will meet the applicable requirements of:
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(i)R307-403,Permits:New and Modified Sources in Nonattainment Areas andMaintenanceAreas;
(H)R307-405,Permits:Major Sources in Attainment or Unclassified Areas (PSD);(iii)R307-406,Visibility;
(iv)R307-410,Emissions Impact Analysis;
(v)R307-420,Permits:Ozone Offset Requirements in Davis and Salt Lake Counties;(vi)R307-210,National Standards of Performance for New Stationary Sources;(vii)National Primary and Secondary Ambient Air Quality Standards;(vHi)R307-214,National Emission Standards for Hazardous Air Pollutants;(ix)R307-110,General Requirements.Utah State Implementation Plan;and(x)All other provisions of R307.
(2)AT&T’s AO will require that all pollution control equipment be adequately and properly maintained.(3)Receipt of an NJ does not relieve any owner or operator of the responsibility to comply with theprovisionsofR307ortheStateImplementationPlan.
BACT provisions specified in UAC R307-401 have been applied through control equipment installed andmonitoringconditions.
AT&T will comply with all applicable requirements detailed above.
8.1.7 IJAC R307-414 Permits:Fees for Approval Orders:
Fees associated with the submission of this NOl air permit application are addressed in Section 1 of thissubmittal.
8.2 Federal Rules:National Emission Standards for Hazardous Air
Pollutants
The NESHAP federal regulations found in Title 40 Parts 61 and 63 of the CFR are emission standards for HAPs.NESI-IAP are applicable to both major sources of HAPs (facilities that exceed the major source thresholds of10tpyofasingleHAPand25tpyofanycombinationofHAP5ftomstationarysources)as well as non-majorsources(termed “area sources”).NESHAP apply to sources in specifically regulated industrial sourceclassifications(Clean Air Act Section 112(d))or on a case-by-case basis (Clean Air Act Section 112(g))forfacilitiesnotregulatedasaspecificindustrialsourcetype.
AT&T is an area source under the NSR program.As such,this document only addresses regulatory applicabilityforareasourcesanddoesnotincludestandardsformajorsources.
8.2.1 Subpart A —General Provisions
NESHAP Subpart A,General Provisions,contains national emissions standards for HAPs defined in Section112(b)of the Clean Air Act.All affected sources,which are subject to another NESHAP are subject to thegeneralprovisionsofNESHAPSubpartA,unless specifically excluded by the source-specific NEHSAP.SubpartArequiresinitialnotification,performance testing,recordkeeping,and monitoring,provides referencemethods,and mandates general control device requirements for all other subparts.The following sectionsdetailingeachsubpartrequirementsalsoincludesrequirementsthatarereferencedtoSubpartA.
AT&T!NOT App’ication
Trinity Consultants
8-6
8.2.2 Subpart ZZZZ —Stationary Reciprocating Internal Combustion Engines
NESHAP Subpart ZZZZ,National Emission Standards for Hazardous Air Pollutants for Stationary ReciorocatingInternalCombustionEngines,applies to stationary reciprocating internal combustion engines (RICE)at majorandareasourcesofHAP5.Per 40 CER 63.6590(a)(2)(iii),a stationary RICE at an area source of HAPs is newifconstructioncommencedafterJune12,2006.Thus,the proposed engine is considered a new stationaryRICEunderNESHAPSubpartZZZZ.Per 40 CFR 63.6590(c)and 40 CFR 63.6590(c)(1),new stationary RICElocatedatanareasourceofHAPmayshowcompliancewithNESHAPZZZZbymaintainingcompliancewithNSPS1111.16 AT&T is not a major source of HAP5,as total HAP emissions amount to less than It tons peryearforanindividualHAPandlessthan25tonsperyearoftotalHAP5.By maintaining compliance with NSPSXIII,AT&T can demonstrate compliance with NESHAP ZZZZ.
8.3 Federal Rules:New Source Performance Standards
NSPS requires new,modified,or reconstructed sources to control emissions to the level achievable by thebestdemonstratedtechnologyasspecifiedintheapplicableprovisions.Moreover,any source subject to NSPSisalsosubjecttothegeneralprovisionsofNSPSSubpartA,except as noted.The following section details theapplicabilityofNSPSregulationstofacilityoperations.
8.3.1 Subpart A-General Provisions
All affected sources subject to source-specific NSPS are subject to the general provisions of NSPS Subpart Aunlessspecificallyexcludedbythesource-specific NSPS.Subpart A requires initial notification,performancetesting,recordkeeping,and monitoring,provides reference methods,and mandates general control devicerequirementsforallothersubparts.
8.3.2 NSPS Subpart 1111 —Standards of Performance for Stationary CompressionIgnitionInternalCombustionEngines
NSPS Subpart 1111,Standards of Performance for Stationary Compression Ignition Internal CombustionEngines,establishes requirements for stationary compression ignition internal combustion engines for whichconstruction,modification,or reconstruction commenced after July 11,2005.
The provisions of this subpart are applicable to owners and operators of compression ignition internalcombustionengineswhichcommencedconstructionafterJuly11,2005 and were manufactured after April 1,2006.The construction date is the date the engine was ordered by the owner or operator.The enginepoweringthegeneratorproposedinthisapplicationwasconstructedafterthespecifiedconstructiondates.NSPS 1111 is applicable to this engine.
Emission Limitation
•Emergency Engines
+Emergency stationary CI ICE with a displacement of <10 liters per cylinder that are not fire pumpenginesmustcomplywiththeemissionstandardsfornewnonroadCIenginesin§60.4202(a),forallpollutants,for the same model year and maximum engine power for their 2007 model year andlateremergencystationaryCIICE.’7
•All Emergency Engines
16 NESHAP Subpart 40 CFR 63.6675.
‘40 CFR 60.4205(b).
AT&T /NOl Application
Trinity Consultants
8-7
•These limitations must be met for the life of the engine.’8
Fuel Requirements
Owners and operators of stationary CI ICE subject to this subpart with a displacement of less than 30
liters per cylinder that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR
80.510(b)for nonroad diesel fuel,except that any existing diesel fuel purchased (or otherwise obtained)
prior to October 1,2010,may be used until depleted.’9
•The requirements of 40 CER 80.510(b)are as follows:
•1)15 ppm sulfur,and
•2)minimum cetane index of 40 or maximum aromatic content of 35 volume percent.
Monitoring Requirements
•Each CI ICE that does not meet the standards applicable to non-emergency engines,must install a
non-resettable hour meter prior to startup of the engine.20
•Each CI ICE equipped with a diesel particulate filter to comply with the emission standards in §60.4204,
the diesel particulate filter must be installed with a backpressure monitor that notifies the owner or
operator when the high backpressure limit of the engine is approached.21
Compliance Requirements
•Operate,maintain,install,and configure the stationary CI internal combustion engine and control
device according to the manufacturer’s emission-related written instructions;22
•Change only those emission-related settings that are permitted by the manufacturer;23
•Meet the requirements of 40 CFR 89,94,and/or 1068;24
•Stationary CI internal combustion engine must comply with the emission standards specified in
§60.4204(b)or §60.4205(b).25
Emergency Engines20
•The engine may be operated for 100 hours per calendar year for maintenance checks,readiness testing,
periods where there is a deviation of voltage or frequency of 5 percent or greater below standard
voltage or frequency,and/or up to 50 hours per calendar year in non-emergency situations.
•No limit for emergency usage of the engine in emergency situations.
Recordkeepinl7
•Using the non-resettable hour meter,a record of the engine’s emergency operation must be kept.The
records must contain the time of operation and the reason the engine was in operation.
18 40 CFR 6C.4206.
134Q CER 60.4207(b).
2040 cFR 60.4209(a).
21 40 CFR 60.4209(b).
2240 CR 60.4211(a)(1).
2340 CFR 60.4211(a)(2).
24 40 CER 60.4211(a)(3).
40 CFR 60.4211(c).
264Q CFR 60.4211(f).
40 CFR 60.4214(b)
AT&T!NOl Application
Trinity consultants 8-8
•AT&T also retains records to indicate that the engine is certified to the emission standards required for
the appropriate manufacture year and size.28
284Q CER 60.4211(c).
AT&T?NOT Application
Trinity Consultants 8-9
APPENDIX A.FORMS
AT&T!NOl Application
Trinity Consultants A 1
Form I Date 1/24/2024
Notice of Intent (NOl)Application Checklist
Corn any AT&T Communications ofojie Mountain Stains,Inc.
Utah Division of Air Quality
New Source Review Section
AIR QUALITY
Source Identification Information [R307-401-5]
I.Company name,mailing address,physical address and telephone number U
2.Company contact (Name,mailing address,and telephone number)
3.Name and contact of person submitting NOl application (if different than 2)
4.Source Universal Transverse Mercator (UTM)coordinates
5.Source Standard Industrial Classification (SIC)code
6.Area designation (attainment,maintenance,or nonattainment)
7.Federal/State requirement applicability (NAAQS,NSPS,MACT,SIP,etc.)
8.Source size determination (Major,Minor,PSD)
9.Current Approval Order(s)and/or Title V Permit numbers
NOl Application Information:[R307-4Olj
I.Detailed description of the project and source process
2.Discussion of fuels,raw materials,and products consumed/produced
3.Description of equipment used in the process and operating schedule
4.Description of changes to the process,production rates,etc.
5.Site plan of source with building dimensions,stack parameters,etc.
6.Best Available Control Technology (BACT)Analysis [R307-401-8]
A.BACT analysis for all new and modified equipment El
7.Emissions Related Information:[R307-401-2(b)j
A.Emission calculations for each new/modified unit and site-wide
(Include PM10,PM25,NO,SO,CO.VOCs,HAPs,and GHGs)
B.References/assumptions,SDS,for each calculation and pollutant
C.All speciated HAP emissions (list in lbs/br)
8.Emissions Impact Analysis —Approved Modeling Protocol [R307-410]
A.Composition and physical characteristics of effluent U
(emission rates,temperature,volume,pollutant types and concentrations)
9.Nonattainment/Maintenance Areas —Major NSRJMinor (offsetting only)[R307-403j
A.NAAQS demonstration,Lowest Achievable Emission Rate,Offset requirements El N/A S
B.Alternative site analysis,Major source ownership compliance certification U N/A S
10.Major Sources in Attainment or Unclassified Areas (PSD)[R307-405,R307-4061
A.Air quality analysis (air model,met data,background data,source impact analysis)U N/A C
B.Visibility impact analysis,Class I area impact U N/A S
11.Signature on Application El
Note:The Division of Air Quality will not accept documents containing confidential information or data.
Documents containing confidential information will be returned to the Source submitting the application.
Form 2 Date 1/24/2024
Company InformationlNotice of Intent (NOl)
Utah Division of Air Quality
New Source Review Section
Application for:Initial Approval Order Approval Order Modification
General Owner and Source Information
1 Company name and mailing address:2.Company**contact for environmental matters:
Julianne BarnumAT&T Communications of the Mountain
States.Inc.1311 S Akard St.12th Floor.Phone no.:([phone]
Dallas,TX 75202
Email:[e-mail]
Phone No.:41 5)454-9282
Fax No.:2s1))664—4201 Company contact only;consultant orindependent contractor contact
information can be provided in a cover letter
3.Source name and physical address (if different from 4.Source Property Universal Transverse Mercator
above):coordinates (UTM),including System and Datum:
AT&T Communications of the UTM:12
Mountain States,Inc.1760 North Highway
38,Brigham City,Utah 84302-3711 X 41.5471653379
Y:112.0149752101Phoneno.:([phone]
Fax_no.:((281)_664-4201
5.The Source is located in:_Box Elder County 6.Standard Industrial Classification Code (SIC)
48t3_
7.If request for modification,AO#to be modified:DAQE #ANO141 260001 -08 DATED:‘l12008
8.Brief (50 words or less)description of process.
The Brigham City,Utah,AT&T Communications of the Mountain States,Inc.location is seeking to
modify Approval Order Number DAQE-AN0141260001-08 to remove 3-15kW engines,add a 40kW
portable engine,and update the capacity of Diesel Fuel Storage Tank 1.
Electronic NOl
9.A complete and accurate electronic NOl submitted to DAQ Permitting Mangers Jon Black (jibIackutah.gov)or Alan
Humpherys (ahumpherysutah.gov)can expedite review process.Please mark application type.
Hard Copy Submittal Electronic Copy Submittal BoihE
Authorizationlsignature
I hereby certify that the information and data submitted in and with this application is completely true.accurate and
complete,based on reasonable inquiry made by me and to the best of my knowledge and belief.
Signature:(4f#X2 4’a.—..Title:Assistant Secretary
Telephone Date:
Jeramiah W.German ttnP20U52$4 3.7.2’-1Email:
Name (Type or print)G43913@attcom
AIR QUALITY
1 of 1
Form 4 Company AT&T Communications of the Mountain States,Inc
Project Information
Utah Division of Air Quality
New Source Review Section
Site Brigham City,Box Elder County,Utah
AIR QUALITY
Process Data -For ModificationlAmendment ONLY
1.Permit NumberANO14260001.Oe
If submitting a new permit then use Form 3
Requested Changes
2.Name of process to be modified/added:3.Permit Change Type:New Increase*
EGEN1;EGEN2:EGEN3;Tank 1;EGEN6 Equipment Ri
Process D D
End product of this process:
Condition Change
Electricity production Other
Other
Other
4.Does new emission unit affect existing 5.Condition(s)Changing:
permitted process limits?
Yes No
6.Description of Permit/Process Change**
AT&T Communications of the Mountain States,Inc.,located at 1760 North Highway 38 in Brigham City,
Box Elder County,Utah,is seeking to remove from operation three 15 kW emergency/standby diesel
powered generators [EGEN1;EGEN2;and,EGEN3],and update the capacity of diesel fuel storage tank
[Tank 1]from 4,000 gallons to 8,000 gallons.Additionally,the Site is requesting to operate a 40 kW
portable diesel powered generator [EGEN6].
7.New or modified materials and quantities used in process.
Material .Quantity Annually
Diesel ‘35,010 gallons/year
8.New or modified process emitting units **
Emitting Unit(s)Capacity(s)Manufacture Date(s)
Tank I (rrooified)8.000 gallons
EGEN 6 (added)40 kW Iami/ga
EGEN 1 (removed)15 kW
EGEN 2 (removed)15 kW
EGEN 3 (removed)15 kW
*ff the permit being modified does not include CO,e or PM,5,the emissions need to be calculated and submitted to DAQ,which may result in an
emissions increase and a public comment period.
**lf additional space is required,please generate a document to accommodate and attach to form.
Page 1 of 1
Form 5
Emissions Information
CriterialGHGsl HAP’s
Utah Division of Air Quality
New Source Review Section
Total HAP 0.0039 0.00 0.0039
Use additional sheets for pollutants if needed
AIR QUALITY
Company AT&T Communications of the Mountain States.Inc.
Ste Brigham City,Box Elder County,Utah
Potential to Emit*Criteria Pollutants &GHGs
Criteria Pollutants Permitted Emissions Emissions Increases Proposed Emissions
(tons!yr)(tonslyr)(tonstyr)
PM10 Total
PM10_Fugitive
PM25
NO,
so2 See Attached f Emission lntorm tion
CO
VOC
VOC_Fugitive
NH3
Greenhouse Gases C02e £Qz £22Z
Co2
CH4
N,O
HFCs See Attached ft r Emission Informs Lion
PFCs
SF6
Total C02e
*potential to emit to include pollution control equipment as defined by R307-401-2.
Hazardous Air Poll utants**(Defined in Section 112(b)of the Clean AirAct
Hazardous Air Permitted Emissions Emission Increase Proposed Emission Increase
Pollutant***(tonslyr)(tonslyr)Emission (tons!yr)(Ibslhr)
See Attachec for Emission Information
Page 1 of I
Utah Division of Air Quality
New Source Review Section
Form 17
Diesel Powered Standby Generator
Company:AT&T Communications of the Mountain States.Inc.
Site/Source:Snghan,City.Dcx Oder County,Utari
Date:1/9/2024
Company Information
1.Company Name and Address:2.Company Contact:
AT&T Communications of the Mountain States.Inc..Iiilinne Rarniim
1311 5 Akard St.12th Floor,Dallas,TX 75202 AT&T Communications of the Mountain States,
Inc.1311 5 Akard St,12th Floor,Dallas.TX
152U2
Phone Number 415-454-9282 Phone Number:214-208-5264
Fax Number:281-664-4201 Fax Number:281-664-4201
3.Installation Address:
AT&T Communicptinnc nf the Mnuntain States Inc County where facility is located:Box Elder
1760 North Highway 38,Brigham City,Utah 84302
Latitude,Longitude and UTM Coordinates of Facility
UTM:4,599,785 meters Northing,415,346 meters Easting.Zone 12
Phone Number:415-454-9282 Latitude:41.5471653379;Longitude:-112.014975210?
Fax Number:2816644201
Standby Generator Information
4.Engines:EGEN6
Maximum Maximum Emission Rate Date the engine
Manufacturer Model Rated Hours of Rate of NO,was constructed
Horsepower or Kilowatts Operation grams/BHP-HR or reconstructed
Perkins 204811 800IG 40 kW 500 December 1998
Attach Manufacturer-supplied information
5.Calculated emissions for this equipment:
PM0_____________Lbs/hr PM25_____________Lbs/hr
yr NO5 See Lbs/sax Lbs/hr Tons/yr
hr Tons/yr CO VOC Tons/yr
Tons/yr CH4 Tons/yr
CO2 See Attached for Emission InformationHAPs_____________Lbs/hr (speciate)Tons/yr
Subm(eWJIons as an appendix.If other pollutants are emitted,include the emissions in the appendix.
Instructions Form 17 -Diesel Powered Standby Generator
Call the Division of Air Quality (DAQ)at [phone] if you have problems or questions in fdhing out
this form.Ask to speak with a New Source Review engineer.We will be glad to help!
Lines I Fill in the name,address,phone number,and fax number of the business applying for the
and 2:permit exemption.
Line 3 Fill in the address where the equipment will be located.Directions to business if needed for remote locations,
i.e.,five miles south of Deseret on highway 101,turn left at farmhouse,go 1.5 miles.Identify the county the
equipment will be located.Also enter the latitude,longitude and UTM coordinates of the facihty.
Line 4 Fill in the manufacturer,model,maximum rated horsepower or kilowatts,maximum hours of operation,emission
rate for NO,in grams/BHP-hr,and the date the engine was constructed or reconstructed.Attach manufacturer
emission information.
Note:Maximum rated horsepower not to exceed 1 000hp or 750 kilowatts.Also maximum hours not to exceed
300 hours.
Line 5 Supply calculations for all criteria pollutants,greenhouse gases and hazardous air pollutants.Use EPA AP-42
or manufacturers’data to complete your calculations.Fill in the name,address,phone number,and fax number
of the business applying for the
U:\aq\ENGINEER\GENERIc\Forms 201 0\Forml7 Diesel-fired Standby Generatcrs,doc
Revised 12/20/10
Utah Division of Air Quality
New Source Review Section
Form 20
Organic Liquid Storage Tank
Equipment
Company:AT&T Communications of the Mountain Slates!Inc.
Site/Source:Brigham City,Box Elder county,Utah
Date:1/9/2024
1.Tank manufacturer:2.Identification number Tank 1
3.Installation date:4.Volume:8.000 gallons
5.Inside tank diameter:feet 6.Tank height:feet
7.True vapor pressure of liquid:psia 8.Reid vapor pressure of liquid:psi
9.Outside color of tank:10.Maximum storage temperature:
11.Average throughput:31.500 gallons per year 12.Turnovers/yearly Monthly —Weekly —
13.Average liquid height (feet):14.Access hatch:Yes No Number
15.Type of Seals:16.Deck Fittings:
a.Primary seals:Gauge float well D Yes No Number_____
C Mechanical shoe Gauge hatch?
a Resilient filled sample well a Yes a No Number_____
a Liquid filled Roof drains a Yes a No Number_____
a Vapor mounted Rim vents a Yes a No Number_____
a Liquid mounted Vacuum break a Yes a No Number_____
a Flexible wiper Roof leg a Yes a No Number_____
b.Secondary seal:Ladder well a Yes a No Number_____
Type:Column well a Yes a No Number_____
Other:_________________________________________
17.Shell Characteristics:18.Type of Construction:
Condition:a Vertical Fixed Roof
Breather Vent Settings:a Horizontal Fixed Roof
Tank Construction:a Internal Floating Roof
Roof Type.a External Floating Roof
Deck Construction:
..a Other (please specify)
Deck Fitting Category:
19.Additional Controls:
a Gas Blanket a Venting a Carbon Adsorption a Thermal Oxidation a Other_______________
20.Single Liquid Information
Liquid Name:Fuel Oil No.2 Liquid Name:
CAS Number:68476-30-2 CAS Number:
Avg.Temperature:675 F Avg.Temperature:
Vapor Pressure:0.1 PSI Vapor Pressure:
Liquid Molecular Weight:Liquid Molecular Weight:
Page 1 of 2
Form 20 -Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name:Chemical Name:
Percent of Total Liquid Weight:Percent of Total Liquid Weight:
Molecular Weight:Molecular Weight:
Avg.Liquid Temperature:Avg.Liquid Temperature:
Vapor Pressure:Vapor Pressure:
Emissions Calculations (PTE)
22.Calculated emissions for this device:
VOC Tons/yr See Attached for Emission Information
HAPs Lbs/hr (speciate)Tons/yr (speciate)
Submit calculations as an appendix.Provide Material Safety Data Sheets for products being stored.
Instructions
Note:1.Submit this form in coniunction with Form I and Form 2.
2.Call the Division of Air Quality (DAQ)at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer.We will be glad to help!
1.Indicate the tank manufacturers name.
2.Supply the equipment identification number that will appear on the tank.
3.Indicate the date of installation.
4.Indicate the capacity of the tank in gallons or barrels.
5.Specify the inside tank diameter in feet.
6.Specify the tank height in feet.
7.Indicate the true vapor pressure of the liquid (psia).
8.Indicate the Reid vapor pressure of the liquid (psi).
9.Indicate the outside color of the tank.
10.Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11.Indicate average annual throughput (gallons).
12.Specify how many times the tank will be emptied and refilled per year,month or week.
13.Specify the average liquid height (feet).
14.Indicate whether or not the tank has access hatches and the number.
15.Indicate what type of seals the tank has.
16.Indicate what types of deck fittings are installed.
17.Specify condition of the tank,also include the following:
Breather vent settings in (psig)for fixed roof tanks
Tank construction,welded or riveted
Roof type;pontoon,double deck,or self-supporting roof
Deck construction;bolted or welded,sheet or panel construction sizes and seam length
Deck fitting category;typical,controlled,or detail
18.Indicate the type of tank construction.
19.Indicate other types of additional controls which will be used.
20.Provide information on liquid being stored,add additional sheets as necessary.
21.Provide information on chemicals being stored,add additional sheets as necessary.
22.Supply calculations for all criteria pollutants and HAPs.Use AP-42 or manufacturers’data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form2O Organic Liquid Storage Tanks.doc
Revised 12/20/10
Page 2 of 2
APPENDIX B.EMISSIONS CALCULATION
AT&T!NOl Application
Trinity Consultants B-i
Brigham City.UT Facility
Potential Emissions C,Iculati on
Table 1.Emissions Summary
Unit Group Potential Annual Emissions (tpy)
NOn CO PMie PM,5 SO,VOC Tool HAP
Currently Permitted Units
Emergency generators 8.20 1.08 0.25 0.25 0.14 0.25 3.900-03
Pre’,i ossly accosr ted for rank -----4.455-04 -
Proposed Units
Emergercy Generator 0.42 0.09 0.03 0.03 0.01 0.03 3.SSE’04
Actaal rank -.-1.11 0-03 9.800-55
Currently Permitted and to be Removed
Emergency Gene raters I 0,16 I 0.03 I 1,125-02 1 .12502 I 2.05E03 I 1.28E02 I ‘.00t04
TOtals
New SiseTotals 8.46 1,93 0,26 0.26 0,14 0.27 3,6E-O2
CurrenEPermitted flEt 8.51 1.94 0.27 0.27 0.17 0.27 3.90t3
Proposed Change in PIt -0,05 ‘0.01 -0.01 -0.01 -0.03 0.00 5.530-05
Major Source ThreshoLds 100 100 100 70 70 70 25/10
txceedirg Major Source Thresholds?5’No No No No No No No
Modeling ThreshoLd?40 -15 -40 -See HAP3 Summary
Modeling Rngsired?No No No No No No No
0.rhese cmi ruins tntals represe no the limit tisen in EAOE-AtnlErs0088l-36
2.Mnjsr seursethres betas are defined Dy 40 tFE sn.lesln)t,llinftu)and 48 EFE s2.2lEblf,ltil(sj
rsnol HAP roresjnnld is stated ia4a tnt Sectiae 51 under deruisitier er a Major Snarce.
4.Medeling tin his stated ir IL 055 emissiess impact Assessment Gui deiisee under muLe ii TataL cnstrnlLed nmnissies gates fer tee sources.
Table 2-1.Stationary Generator Information
1.Based on manufactorer specifications.
Co 5.50E-03 3.69 1.84
PM102 7.OOE-04 0.47 0.23
PM252 7.OOE-04 0.47 0.23
SO2 4.OSE-04 0.27 0.14
VOC 7.05E-04 0.47 0.24
1.Source:EPA AP 42,Votume I,Fifth Edition,Table 3.4-1.
2.Conservatively assumed PM=PM,0=PM25
3.sample emissions calculation:Potential Emissions (lb/hr)=Emission Factor (lb/hp-hr)*Output Capacity (hp)
Table 2-3.Proposed Portable Generator Information
Annual Hours of Operation (per Generator):500 hr/yr
.1 40 kW
Output Capacity (per Generator):hp
Number of Generators:1
Fuel1:Fuel Oil No.2
%Sulfur1:0.05
Fuel Consumption (per Generator)1:2.96 gal/hr
Maximum Annual Fuel Consumption (per Generator):1,480 gal/yr
1.Based on manufactorer specifications.
Table 2-4.Proposed Portable Generator Emissions
NO 0.031 1.66 0.42
CO 6.68E-03 0.36 0.09
PM10 2.20E-03 0.12 0.03
PM252 2.20E-03 0.12 0.03
502 4.o5E-04 0.02 0.01
VOC 2.51E-03 0.13 0.03
i.source:EPAAP 42,volume i,Fifth Edition,Table 3.3-1.
2.Conservatively assumed PM1QZPM2
3.sample emissions calculation:Potential Emissions (lb/hr)=Emission Factor (lb/hp-hr)•Output Capacity (hp)
IIii[4 Fji1g IffflL
Annual Hours of Operation (per Generator):500 hr/yr
.
500 kW
Output Capacity (per Generator)671 hp
Number of Generators:2
Fuel1:Fuel Oil No.2
%Sulfur1:0.05
Fuel Consumption (per Generator)1:33.53 gal/hr
Maximum Annual Fuel Consumption (per Generator):16,765 gal/yr
Table 2-2.Stationary Generator Emissions
NO 0.024 16.09 8.05
Parameter Value Units
Table 2-5.To be Removed Stationa.Generator In formation
1.Based on manufactorer specifications.
hp
Table 2-6.To be Removed Stationary Generator Emissions
CO 6.68E-03 0.13 0.03
PM10 2.20E-03 0.04 1.12E-02
PM252 2.20E-03 0.04 1.12E-02
502 4.05E-04 0.01 2.05E-03
VOC 2.51E-03 0.05 l.28E-02
1.Source:EPA AP 42,volume i,Fifth Edition,Table 3.3-1.
2.Conservatively assumed PM10=PM25
Annual Hours of Operation (per Generator):
Parameter VaLue Units
Output Capacity (per Generator)1:
500
15 kW
20
Number of Generators:3
Fue’:FueL Oil No.2
%SuLfur1:0.05
FueL Consumption (per Generator)1:1.01 gaL/hr
Maximum AnnuaL FueL Consumption (per Generator):505 gaL/yr
NO,0.031 0.62 0.16
3.Sample emissions catculation:Potential Emissions (lb/hr)=Emission Factor (lb/hp-hr)*Output Capacity (hp)
Table 3.Diesel Storage Tank Emissions
150 Aboveground 31,500 0.21 1.05E-04
150 Aboveground 31,500 0.21 1.05E-04
PreviousLy accounted for Tank
4,000 Underground 31,500 0.47 2.35E-04
Actual Tank
8,000 Underground 35,010 2.23 1.11E-03
1.FaciLity-Wide Maximum Annual Fuel consumption:
35,010 gal/yr
2.Source:EPA TANKS program emissions caLculation summary for 150-gallon and 4,000 galLon tanks and Tank ESP
program emissions caLcuLation summary for 8,000-gaLLon tank.
3.The maximum annuaL throughput for the 150-gaLlon and 4,000 gaLlon tanks is 31,500 gaLLons per year
and the maximum annuaL throughput for the 8,000 galLon tank is 35,010 galLons per year;therefore,the
total voc emissions from all tanks is best represented by the the cooresponding maximum throughputs.
Acrolein 2.83E-05 2.72E-05 -1.09E-06 -4.34E-06 --
Benzene 1.92E-03 1.91E-03 -8.62E-06 -3.45E-05 0,32 No
Formaldehyde 3.10L-04 2.96E-04 -1.38-05 -554E-05 0.06 No
Toluene 7.03E-04 7.24E-04 2.15E-05 861L-05 14.92 No
Xylenes 483E-04 557E-04 7.35L-05 2.94E-04 --
1.3-Butadiene 4.13E-06 3.67E-06 -4.59E-D7 -1.84E-06 0.29 No
Other HAPs 3.14E-04 3.17E-04 3.29E-06 1.32E-05 --
Table 4.HAPs Summary
Acetaldehyde --1 .40E-04 1.31 E-04 -9.OOE-06 -3.60E-05 6.94 No
iieC,sIo IlTri952
202ND 0 23 50-:014 1.1025 5.25 54 flOE-OS ‘16r06 I 68-05 -0 --31 01 256E-O5
EGENS 0 ns&.15 DC 1 0.14 2.?025 3.16304 U0005 6.162-68 1 44100 -322-:1 21CE 236 c_c’
51504 0 ost.500 630.5 469 2.660-06 915868 9.?C-Os 636006 1302-04 -I 1360s .53E<4
11(90 Dose.500 630.5 1.69 2.660-05 SE16 9.?0-04 9.10205 33004 -2 265-Oo t93r<4
03696 Diese.40 036 C 56 7202-09 6.466-06 6262-09 16<4 3.0465 3.676-05 2.635-09 7.368-04
Tr6-60005.i Des,:-.---236<6 -2.08-50 -6.52-03 42006
5JFS 5I6U6nF.Own —Diesel ISUnSUiJO bi.,,(0500 Ic).
1.Fmissiol factsesla605 23455 5F-42.
Chapter 1,lablo 7.3-1
(Speciased Org ao23 CdatFoasId
Emission carton foe bsscsesrslled
Diesel On glees).
loge,(n.i,3os Footnes toe Lance Som o..a7 Diesel b.gOses (5 500 bpS.
1-Emission facts,.takon from 59-42.
Chapter 4 ToOl,34-5
Ispecissed Or(o&c Compound
Emission Factors for tlecort,ollod
Diesel Engines
(1is I C:i&I 2-:-63’
Cso psosdPolisEostEmissiontenors
IS (‘0 666)’
1S6O5 I 530054 I 4ss6 i lIE-DC --:51-5:I :ii-DO
---_.lehydr -—-
Scro[ein 9292-09
lenoone O54E-t4
Formaldehyde 3.162-03
To 10610 4,59604
Xyloses 2.000-04
1 3-Ostad lOsOl 3,91605
Other 6595 6.400-06
Compoand
Pollutant [mission 10(Iorc
6 IS I 69 69 60 a
-rfltwsssc LtasU
04101635 7,0066
Ornzone 776604
Fsrma)drhydo 3.096-35
Ts)onlr 2.012-04
Sylerres 1.930-go
Other 6665 1-300-34
/sT&tcammim.&iano orson M,s,isa Isaks.[52.
APPENDIX C.SUPPORTING BACT INFORMATION
AT&T!NOT Application
Trinity Consultants C-i
Cost Analyses
Table A-i.Control Cost Evaluation for Replacement Emergency Use Engine -General Information
Parameter Value Notes
Process Information
Duty (kW)40
Duty bhp)54 Approximate conversion from kW to hp is 1.341 hpfkW
11cr I Emission NO,Rate
9.2 U.S.EPA Office of Transportation and Air Quality (U.S.EPA-420-B-16-022)published March 201&(q/kW-hr)
Tier I Emissions NO (tpy)0.04 Total emission rate based on a maximum of 100 hr per year.
U.S.EPA Office of Transportation and Air Quality (U.S.EPA-420-B-16-022)published March 2016.EmissionTierIII&Tier IV Emission NO,Rate 4.70 rate for NMHC+NOx was the published form,NMHC is anticipated to be a minor component of the(g/kW-hr)emission factor.
Controlled emissions provided by Tier IV Final Nonroad Compression-Ignition Engines:Exhaust EmissionTierIVFinalEmissionsNO(tpy)0.02 Standards for NO
Economic Factors
Equipment Ufe Expectancy (Years)
Interest Rate (‘ID)
15 Jxecnpbon to replacement engine provisions codified in 40 CER 60.4210(i)
7.00%[0MB Circular A-4,https://obamawhitehouse.archives.qovfowb/circulars a004 a-4/
Table A-2.Control Cost Evaluation for Replacement Emergency Use Engine -Capital Investment
irl,,flf4
Total Capital Investment($)$19,000 Cost estimate from a reliable vendor for a replacement 30kw engine.Cost in 2023 dollars.
11.5.EPA Cost Control Manual Section 1,Chapter 2 Cost Estimation:Concepts and Methodology,EquationCapitalRecoveryFactor(CRF)0.1098 2.8a
U.S.EPA Cost Control Manual Section 1,Chapter 2 Cost Estimation:Concepts and Methodology,EquationCapitalRecoveryCost(CRC)$2,086 2.8
Trinity consultantsUniversityofUtah
Cost Analyses
Table A-3.Control Cost Evaluation for Replacement Emergency Use Engine -Annual Ooeratinq Costs
Direct Operating Costs
Operating Labor,Maintenance,s/hp,U.S.EPA Alternative Control Techniques Document:Stationary Diesel Engines (U.S.EPA Contract
Brake Specific Fuel Consumption,$4 No.EP-D-07-019)Published March 5,2010,Cost values are cited to be from 2005 and have been lowered
and Catalyst Maintenance to match a run time of 100 hours.
Inflation Factor 1 69 Based on U.S.Bureau of Labor Statistics CR1 Inflation Calculator from January of 2003 to December of
2023.https://www.bls.gov/data/inflation calculator.htm
Total Direct Operating Costs $363
Table A-4.BAa Control Cost (valuation for Replacement Emergency Use Engine -Annual O2erating,Insurance,Tax,and Other Costs
t1t.IiiCl(i a’FlFIT
Votal Annual Cost $2,449 Sum of Capital Recovery Cost,Total Direct Operating Costs,Insurance,Tax and Other Annual Costs.
NO,Cost Per Ton Removed
NO Removed (tpy)0.02
Cost per Ton of NO Removed 3(s/ton)$?4
University of Utah Trinity consultanLs