DAQ-2024-012126

DAQE-AN160660003-24

{{$d1 }}

Anthony Gustin
Novva SLC Common, LLC
6524 West Old Bingham Highway
West Jordan, UT 84081
[e-mail]

Dear Mr. Gustin:

Re: Approval Order: Modification to Approval Order DAQE-AN160660001-22 to Install New Power
Generation Engines
Project Number: N160660003

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on May 30,
2024. Novva SLC Common, LLC must comply with the requirements of this AO, all applicable state
requirements (R307), and Federal Standards.

The project engineer for this action is John Jenks, 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:JJ:jg

cc: Salt Lake County Health Department
EPA Region 8

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

December 19, 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-AN160660003-24
Modification to Approval Order DAQE-AN160660001-22
to Install New Power Generation Engines

Prepared By
John Jenks, Engineer
[phone]
[e-mail]

Issued to
Novva SLC Common, LLC - West Jordan Data Center

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

December 19, 2024
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 .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ..................................................................................................................... 9
ACRONYMS ............................................................................................................................... 10

DAQE-AN160660003-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Novva SLC Common, LLC Novva SLC Common, LLC - West Jordan Data Center

Mailing Address Physical Address
6524 West Old Bingham Highway 6524 West Old Bingham Highway
West Jordan, UT 84081 West Jordan, UT 84081

Source Contact UTM Coordinates
Name: Sophia Gump 411,485 m Easting
Phone: [phone],491,982 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 7376 (Computer Facilities Management Services)

SOURCE INFORMATION
General Description
Novva SLC Common, LLC (Novva) operates a data center in Salt Lake County. The data center houses
servers to store, manage, and disseminate data. The servers require both primary power and backup power
contingencies to preserve services for customers in the case that local power is interrupted.

NSR Classification
Major Modification at Minor Source

Source Classification
Located in Northern Wasatch Front O3 NAA, Salt Lake City UT PM2.5 NAA, Salt Lake County SO2
NAA
Salt Lake County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
DAQE-AN160660003-24
Page 4

MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
MACT (Part 63), DDDDD: National Emission Standards for Hazardous Air Pollutants for
Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters

Project Description
Novva has requested to expand power generation at its existing West Jordan Data Center. The source is
requesting to install 72 new natural gas-fired IC engines, which will power generators providing primary
power for the site's two (2) new data center buildings. In addition, a second change was requested under a
separate NOI submitted on May 30, 2024, which covered multiple updates in both the diesel-fired
emergency engine generators and diesel storage tanks. The equipment list will be updated to reflect these
changes in previously permitted equipment. This project will reclassify the source as a major CO and
HAP source subject to Title V. The source will obtain emission reduction credits in the amount of 47 tpy
of NOx to satisfy the offset requirements of R307-421. Finally, this project also includes updated
modeling based on the equipment changes and some adjustments to stack heights.

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)
Ammonia 61.01
CO2 Equivalent 990854 997261.00
Carbon Monoxide 196.54 202.72
Nitrogen Oxides 43.87 51.28
Particulate Matter - PM10 30.42 30.87
Particulate Matter - PM2.5 30.42 30.87
Sulfur Dioxide 15.22 15.26
Volatile Organic Compounds 46.75 48.28

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
1,3-Butadiene (CAS #106990) 180 182
1-METHYLNAPHTHALENE (CAS #90120) 20 26
2,2,4-Trimethylpentane (CAS #540841) 180 180
Acetaldehyde (CAS #75070) 5700 5700
Acrolein (CAS #107028) 3500 3500
Benzene (Including Benzene From Gasoline) (CAS #71432) 229 300
Biphenyl (CAS #92524) 3620 3620
Ethyl Benzene (CAS #100414) 27 27
Formaldehyde (CAS #50000) 46360 46373
Generic HAPs (CAS #GHAPS) 258 280
Hexane (CAS #110543) 725 760
Methanol (CAS #67561) 1700 1700
Naphthalene (CAS #91203) 51 51
DAQE-AN160660003-24
Page 5

PAH, Total (CAS #234) 18 18
Styrene (CAS #100425) 16 16
Toluene (CAS #108883) 38 280
Xylenes (Isomers And Mixture) (CAS #1330207) -430 120
Change (TPY) Total (TPY)
Total HAPs 31.10 31.56

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 five-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 five (5) 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-AN160660003-24
Page 6

SECTION II: PERMITTED EQUIPMENT

II.A THE APPROVED EQUIPMENT

II.A.1 West Jordan Data Center
II.A.2 Natural Gas-Fired Generator Engines
Seventy-two (72) Jenbacher Model: JGS 620 J715
Rating: 3271.8 kW (4,601 hp)
Control: Selective Catalytic Reduction (SCR) and Oxidation Catalyst
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

II.A.3 Diesel-fired Emergency Generator Engines Seventeen (17) MTU 1500 Rating: 1,736 kW (2,328 hp) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.4 Diesel-fired Emergency Generator Engine
Cat C15 (Office)
Rating: 568 kW (762 HP)
Model Year: 2019
Fuel: ULSD
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.5 Diesel-fired Emergency Generator Engines Eleven (11) Kohler (KD 2500) Rating: 2,700 kW (3,621 HP) each Model Year: 2019 Fuel: ULSD Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.6 Diesel-fired Emergency Generator Engines
Four (4) Cummins 2000
Rating: 2,179 kW (2,922 HP) each
Model Year: 2019
Fuel: ULSD
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.7 Diesel-fired Emergency Generator Engines Two (2) MTU 1750 Rating: 1,910 kW (2,561 HP) each Model Year: 2019 Fuel: ULSD Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
DAQE-AN160660003-24
Page 7

II.A.8 Diesel-fired Emergency Generator Engines Two (2) MTU 2000 Rating: 2,279 kW (3056 HP) each Model Year: 2019 Fuel: ULSD Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.9 Eleven (11) Bulk Diesel Storage Tanks Contents: ULSD Capacity (gallons): 8,000

II.A.10 Four (4) Diesel Belly Tanks Contents: ULSD Capacity (gallons): 3,650 II.A.11 Thirty-two (32) Diesel Day Tanks
Contents: ULSD
Capacity (gallons): 400
II.A.12 Boiler Rating: <5 MMBtu/hr Fuel: Natural Gas NSPS/MACT Applicability: 40 CFR 63 Subpart DDDDD

SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Natural Gas Generator Engine Requirements
II.B.1.a The owner/operator shall not emit more than the following from each natural gas-fired engine on site: A. NOx: 0.0152 g/bhp-hr (0.15 lb/hr) B. CO: 0.065 g/bhp-hr (0.63 lb/hr) C. VOC: 0.0155 g/bhp-hr (0.15 lb/hr). [R307-401-8]
II.B.1.a.1 To demonstrate compliance with these emission rates, the owner/operator shall test each engine
as per the requirements of 40 CFR 60 Subpart JJJJ. [40 CFR 60 Subpart JJJJ, R307-401-8] II.B.1.b The owner/operator shall combust only pipeline-quality natural gas as fuel in each natural gas-fired engine. [R307-401-8]
II.B.1.c The exhaust stack height for each natural gas-fired generator engine shall be no less than 29.9 feet (9.1 meters) as measured from the ground. [R307-401-8]

DAQE-AN160660003-24
Page 8

II.B.2 Emergency Generator Engine Requirements II.B.2.a The owner/operator shall not emit more than the following from each emergency engine on site:
CAT C15: 0.83 lb/hr NOx Cummins 2000: 3.41 lb/hr NOx
MTU 1500 Miratech: 3.33 lb/hr NOx MTU 1500 SafetyPower: 3.33 lb/hr NOx MTU 1750: 3.38 lb/hr NOx
MTU 2000: 3.63 lb/hr NOx Kohler 2500: 6.67 lb/hr NOx
[R307-401-8]
II.B.2.a.1 To demonstrate compliance with the emission rate, the owner/operator shall test each engine as outlined in 40 CFR 60 Subpart IIII. [40 CFR 60 Subpart IIII, R307-401-8] II.B.2.b The owner/operator shall not operate each emergency engine on site for more than 42 hours per
rolling 12-month period during non-emergency situations. There is no time limit on the use of
the engines during emergencies. [40 CFR 60 Subpart ZZZZ, R307-401-8]
II.B.2.b.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 60 Subpart ZZZZ, R307-401-8]
II.B.2.b.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [R307-401-8, 40 CFR 63 Subpart ZZZZ]
II.B.2.c The owner/operator shall perform maintenance and testing of the emergency generator engines in accordance with the following: A. The owner/operator shall not operate more than two (2) emergency generator engines at one time for maintenance and testing operations B. Each emergency generator shall only be tested between the hours of 7:00 a.m. and 7:00 p.m. [R307-410]
II.B.2.c.1 The owner/operator shall:

A. Record the date and time that the maintenance and testing were performed

B. Record the emergency generator engine that was maintained and tested;

C. Maintain records of maintenance and testing.

[R307-401-8]

DAQE-AN160660003-24
Page 9

II.B.2.d The exhaust stack height for the CAT C15 (office) emergency generator engine shall be no less than 9.1 feet (2.8 meters) as measured from the ground. The exhaust stack height for all other emergency generator engines (except the CAT C15 emergency generator) shall be no less than 42 feet (12.8 meters) as measured from the ground. [R307-401-8]
II.B.2.e 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.e.1 The owner/operator shall only combust diesel fuel that meets the definition in 40 CFR 1090.305 of ULSD, which has a sulfur content of 15 ppm or less. [R307-401-8] II.B.2.e.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-AN160660001-22 dated February 23, 2022 Is Derived From NOI dated May 30, 2024 Incorporates Additional Information Received dated May 30, 2024 Incorporates Additional Information Received dated September 13, 2024 Incorporates Additional Information Received dated November 14, 2024
DAQE-AN160660003-24
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 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-IN160660003-24

November 13, 2024

Anthony Gustin
Novva SLC Common, LLC.
6524 W. Old Bingham Highway West Jordan, UT 84081
[e-mail]

Dear Gustin:

Re: Intent to Approve: Modification to Approval Order DAQE-AN160660001-22 to Install New
Power Generation Engines
Project Number: N160660003

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, John Jenks, as well as the DAQE
number as shown on the upper right-hand corner of this letter. John Jenks, can be reached at (385) 306-
6510 or [e-mail], if you have any questions.

Sincerely,

{{$s }}

Jon L. Black, Manager
New Source Review Section

XXX:xx:jg

cc: Salt Lake County Health Department
DJ Law

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

* ) ' & — * 1 @ C v A ? A C @ G w C A ˜
STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

INTENT TO APPROVE
DAQE-IN160660003-24
Modification to Approval Order DAQE-AN160660001-22 to Install
New Power Generation Engines

Prepared By
John Jenks, Engineer
[phone]
[e-mail]

Issued to
Novva SLC Common, LLC.

Issued On
November 13, 2024

{{$s }}

New Source Review Section Manager
Jon L. Black
{{#s=Sig_es_:signer1:signature}}
* ) ' & — * 1 @ C v A ? A C @ G w C A ˜

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............................................................................................... 5
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ..................................................................................................................... 9
ACRONYMS ............................................................................................................................... 10

DAQE-IN160660003-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Novva SLC Common, LLC. Novva SLC Common, LLC.

Mailing Address Physical Address
6524 W. Old Bingham Highway 6524 W. Old Bingham Highway
West Jordan, UT 84081 West Jordan, UT 84081

Source Contact UTM Coordinates
Name: Sophia Gump 411,485 m Easting
Phone: [phone],491,982 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 7376 (Computer Facilities Management Services)

SOURCE INFORMATION
General Description
Novva SLC Common, LLC. (Novva) operates a data center in Salt Lake County. The data center houses
servers to store, manage, and disseminate data. The servers require both primary power and backup power
contingencies to preserve services for customers in the case that local power is interrupted.
NSR Classification
Major Modification at Minor Source
Source Classification
Located in:
Northern Wasatch Front O3 NAA,
Salt Lake City UT PM2.5 NAA,
Salt Lake County SO2 NAA
Salt Lake County
Airs Source Size: A
Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark 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
MACT (Part 63), DDDDD: National Emission Standards for Hazardous Air Pollutants for
Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters
DAQE-IN160660003-24
Page 4

Project Description
Novva has requested to expand power generation at its existing West Jordan Data Center. The source is
requesting to install 72 new natural gas-fired IC engines which will power generators providing primary
power for the site's two new data center buildings. In addition, a second change was requested under a
separate NOI submitted on May 30, 2024 which covered multiple updates in both the diesel-fired
emergency engine generators and diesel storage tanks. The equipment list will be updated to reflect these
changes in previously permitted equipment. This project will reclassify the source as a major CO and
HAP source subject to Title V. The source will obtain emission reduction credits in the amount of 47 tpy
of NOx to satisfy the offset requirements of R307-403-5(1)(c). Finally, this project also includes updated
modeling based on the equipment changes and some adjustments to stack heights.

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)
Ammonia 61.01
CO2 Equivalent 990854 997261.00
Carbon Monoxide 196.54 202.72
Nitrogen Oxides 43.87 51.28
Particulate Matter - PM10 30.42 30.87
Particulate Matter - PM2.5 30.42 30.87
Sulfur Dioxide 15.22 15.26
Volatile Organic Compounds 46.75 48.28

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
1,3-Butadiene (CAS #106990) 180 182
1-METHYLNAPHTHALENE (CAS #90120) 20 26
2,2,4-Trimethylpentane (CAS #540841) 180 180
Acetaldehyde (CAS #75070) 5700 5700
Acrolein (CAS #107028) 3500 3500
Benzene (Including Benzene From Gasoline) (CAS #71432) 229 300
Biphenyl (CAS #92524) 3620 3620
Ethyl Benzene (CAS #100414) 27 27
Formaldehyde (CAS #50000) 46360 46360
Generic HAPs (CAS #GHAPS) 258 280
Hexane (CAS #110543) 725 760
Methanol (CAS #67561) 1700 1700
Naphthalene (CAS #91203) 51 51
PAH, Total (CAS #234) 18 18
Styrene (CAS #100425) 16 16
Toluene (CAS #108883) 38 280
Xylenes (Isomers And Mixture) (CAS #1330207) -430 120
Change (TPY) Total (TPY)
Total HAPs 31.10 31.56
DAQE-IN160660003-24
Page 5

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 Salt Lake Tribune and Deseret News on November 17, 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.
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 five (5) 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-IN160660003-24
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 West Jordan Data Center
II.A.2 Natural Gas-Fired Generator Engines Seventy-two (72) Jenbacher Model: JGS 620 J715 Rating: 3271.8 kW (4,601 hp) Control: SCR and Oxidation Catalyst NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ II.A.3 Diesel-fired Emergency Generator Engines Seventeen (17) MTU 1500 Rating: 1,736 kW (2,328 hp) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.4 Diesel-fired Emergency Generator Engine Cat C15 (Office) Rating: 568 kW (762 HP) Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ II.A.5 Diesel-fired Emergency Generator Engines Eleven (11) Kohler (KD 2500) Rating: 2,700 kW (3,621 HP) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.6 Diesel-fired Emergency Generator Engines Four (4) Cummins 2000 Rating: 2,179 kW (2,922 HP) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ II.A.7 Diesel-fired Emergency Generator Engines Two (2) MTU 1750 Rating: 1,910 kW (2,561 HP) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
DAQE-IN160660003-24
Page 7

II.A.8 Diesel-fired Emergency Generator Engines Two (2) MTU 2000 Rating: 2,279 kW (3056 HP) each Model Year: 2019 Fuel: Ultra-low Sulfur Diesel (ULSD) Control: SCR NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ II.A.9 Eleven (11) Bulk Diesel Storage Tanks
Contents: ULSD Capacity (gallons): 8,000
II.A.10 Four (4) Diesel Belly Tank Contents: ULSD Capacity (gallons): 3,650 II.A.11 Thirty-two (32) Diesel Day Tanks Contents: ULSD
Capacity (gallons): 400
II.A.12 Boiler Rating: <5 MMBtu/hr Fuel: Natural Gas NSP/MACT Applicability: 40 CFR 63 Subpart DDDDD
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 Natural Gas Generator Engine Requirements
II.B.1.a The owner/operator shall not emit more than the following from each natural gas-fired engine on site: A. NOx: 0.0152 g/bhp-hr (0.15 lb/hr) B. CO: 0.065 g/bhp-hr (0.63 lb/hr) C. VOC: 0.00608 g/bhp-hr (0.06 lb/hr). [R307-401-8]
II.B.1.a.1 To demonstrate compliance with these emission rates, the owner/operator shall test each engine
as per the requirements of 40 CFR 60 Subpart JJJJ. [40 CFR 60 Subpart JJJJ, R307-401-8]

II.B.1.b The owner/operator shall combust only pipeline quality natural gas as fuel in each natural gas-fired engine. [R307-401-8]
II.B.1.c The exhaust stack height for each natural gas-fired generator engine shall be no less than 29.9
feet (9.1 meters) as measured from the ground. [R307-401-8]

II.B.2 Emergency Generator Engine Requirements
II.B.2.a The owner/operator shall not emit more than the following from each emergency engine on site:

CAT C15: 0.83 lb/hr NOx
Cummins 2000: 3.41 lb/hr NOx
MTU 1500 Miratech: 3.33 lb/hr NOx
MTU 1500 SafetyPower: 3.33 lb/hr NOx
MTU 1750: 3.38 lb/hr NOx
MTU 2000: 3.63 lb/hr NOx
Kohler 2500: 6.67 lb/hr NOx. [R307-401-8]

DAQE-IN160660003-24
Page 8

II.B.2.a.1 To demonstrate compliance with the emission rate, the owner/operator shall test each engine as outlined in 40 CFR 60 Subpart IIII. [40 CFR 60 Subpart IIII, R307-401-8] II.B.2.b The owner/operator shall not operate each emergency engine on site for more than 42 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of
the engines during emergencies. [40 CFR 60 Subpart ZZZZ, R307-401-8]
II.B.2.b.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 60 Subpart ZZZZ, R307-401-8]
II.B.2.b.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [R307-401-8, 40 CFR 63 Subpart ZZZZ]

II.B.2.c The owner/operator shall perform maintenance and testing of the emergency generator engines in accordance with the following: A. The owner/operator shall not operate more than two (2) emergency generator engines at one time for maintenance and testing operations B. Each emergency generator shall only be tested between the hours of 7:00 a.m. and 7:00 p.m. [R307-410]
II.B.2.c.1 The owner/operator shall:
A. Record the date and time that the maintenance and testing was performed;

B. Record the emergency generator engine that was maintained and tested;
C. Maintain records of maintenance and testing. [R307-401-8]

II.B.2.d The exhaust stack height for the CAT C15 (office) emergency generator engine shall be no less than 9.1 feet (2.8 meters) as measured from the ground. The exhaust stack height for all other emergency generator engines (except the CAT C15 emergency generator) shall be no less than 42 feet (12.8 meters) as measured from the ground. [R307-401-8]
II.B.2.e 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.e.1 The owner/operator shall only combust diesel fuel that meets the definition in 40 CFR 1090.305 of ultra-low sulfur diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8]
II.B.2.e.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]

DAQE-IN160660003-24
Page 9

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Is Derived From Source Submitted NOI dated May 30, 2024 Incorporates Additional Information Received dated May 30, 2024 Incorporates Additional Information Received dated September 13, 2024 Incorporates Additional Information Received dated November 14, 2024 Supersedes DAQE-AN160660001-22 dated February 23, 2022

DAQE-IN160660003-24
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 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

The Salt Lake Tribune
Publication Name:
The Salt Lake Tribune
Publication URL:
Publication City and State:
Salt Lake City, UT
Publication County:
Salt Lake
Notice Popular Keyword Category:
Notice Keywords:
novva
Notice Authentication Number:
202411181100050259265
1761527881
Notice URL:
Back
Notice Publish Date:
Sunday, November 17, 2024
Notice Content
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: Novva SLC Common, LLC. Location: Novva SLC Common, LLC. – 6524 W. Old
Bingham Highway, West Jordan, UT Project Description: Novva has requested to expand power generation at its existing West Jordan Data
Center. The source is requesting to install 72 new natural gas-fired IC engines which will power generators providing primary power for the
site's two new data center buildings. In addition, a second change was requested under a separate Notice of Intent submitted on May 30,
2024 which covered multiple updates in both the diesel-fired emergency engine generators and diesel storage tanks. The equipment list will
be updated to reflect these changes in previously permitted equipment. This project will reclassify the source as a major Carbon monoxide
and Hazardous air pollutant(s) source subject to Title V. The source will obtain emission reduction credits in the amount of 47 tpy of NOx to
satisfy the offset requirements of R307-403-5(1)(c). Finally, this project also includes updated modeling based on the equipment changes
and some adjustments to stack heights. 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 December 17, 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: November 17, 2024 SLT0030281
Back

DAQE-NN160660003-24

November 13, 2024

Salt Lake Tribune and Deseret News
Legal Advertising Dept.
P.O. Box 704055Acct #9001399880
West Valley City, UT 84170

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Salt Lake Tribune and
Deseret News on November 17, 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 }}

Teri Houskeeper
Office Technician

Enclosure

cc: Salt Lake 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-NN160660003-24
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: Novva SLC Common, LLC.
Location: Novva SLC Common, LLC. – 6524 W. Old Bingham Highway, West Jordan, UT
Project Description: Novva has requested to expand power generation at its existing West Jordan Data
Center. The source is requesting to install 72 new natural gas-fired IC engines
which will power generators providing primary power for the site's two new data
center buildings. In addition, a second change was requested under a separate
Notice of Intent submitted on May 30, 2024 which covered multiple updates in
both the diesel-fired emergency engine generators and diesel storage tanks. The
equipment list will be updated to reflect these changes in previously permitted
equipment. This project will reclassify the source as a major Carbon monoxide
and Hazardous air pollutant(s) source subject to Title V. The source will obtain
emission reduction credits in the amount of 47 tpy of NOx to satisfy the offset
requirements of R307-403-5(1)(c). Finally, this project also includes updated
modeling based on the equipment changes and some adjustments to stack
heights.

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 December 17, 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: November 17, 2024

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

DAQE-
RN160660003
November 5, 2024
Anthony Gustin
Novva SLC Common, LLC.
6524 W. Old Bingham Highway
West Jordan, UT 84081
[e-mail]
Dear Anthony Gustin,
Re: Engineer Review:
Modification to Approval Order DAQE-AN160660001-22 to Install New Power Generation
Engines
Project Number: N160660003
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. Novva SLC
Common, LLC. should complete this review within 10 business days of receipt.
Novva SLC Common, LLC. should contact John Jenks at [phone] if there are questions or
concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email
John Jenks 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 Novva SLC Common, LLC. does not respond to this letter within 10 business days, the project will
move forward without source concurrence. If Novva SLC Common, LLC. 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
Lieutenant Governor
11/06/2024
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW
SOURCE INFORMATION
Project Number N160660003
Owner Name Novva SLC Common, LLC.
Mailing Address 6524 W. Old Bingham Highway
West Jordan, UT, 84081
Source Name Novva SLC Common, LLC.
Source Location 6524 W. Old Bingham Highway
West Jordan, UT 84081
UTM Projection 411,485 m Easting, 4,491,982 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 7376 (Computer Facilities Management Services)
Source Contact Sophia Gump
Phone Number [phone]
Email [e-mail]
Billing Contact Anthony Gustin
Phone Number [phone]
Email [e-mail]
Project Engineer John Jenks, Engineer
Phone Number [phone]
Email [e-mail]
Notice of Intent (NOI) Submitted May 30, 2024
Date of Accepted Application September 13, 2024
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 2
SOURCE DESCRIPTION
General Description
Novva SLC Common, LLC. (Novva) operates a data center in Salt Lake County. The data center
houses servers to store, manage, and disseminate data. The servers require both primary power
and backup power contingencies to preserve services for customers in the case that local power is
interrupted.
NSR Classification:
Major Modification at Minor Source
Source Classification
Located in:
Northern Wasatch Front O3 NAA,
Salt Lake City UT PM2.5 NAA,
Salt Lake County SO2 NAA,
Salt Lake County
Airs Source Size: A
Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark 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
MACT (Part 63), DDDDD: National Emission Standards for Hazardous Air Pollutants for
Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters
Project Proposal
Modification to Approval Order DAQE-AN160660001-22 to Install New Power Generation
Engines
Project Description
Novva has requested to expand power generation at its existing West Jordan Data Center. The
source is requesting to install 72 new natural gas-fired IC engines which will power generators
providing primary power for the site's two new data center buildings. In addition, a second
change was requested under a separate NOI submitted on May 30, 2024 which covered multiple
updates in both the diesel-fired emergency engine generators and diesel storage tanks. These
additional changes were submitted under the exemption provisions of R307-401-12 - Reduction
in Air Pollutants. The equipment list will be updated to reflect these changes in previously
permitted equipment. This project will reclassify the source as a major CO and HAP source
subject to Title V. The source will obtain emission reduction credits in the amount of 47 tpy of
NOx to satisfy the offset requirements of R307-403-5(1)(c). Finally, this project also includes
updated modeling based on the equipment changes and some adjustments to stack heights.
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 3
EMISSION IMPACT ANALYSIS
Novva is proposing to modify the West Jordan Facility by installing seventy-two (72) natural gas-fired
generators to provide prime power to two (2) new data center buildings onsite: Building 2 and Building 3.
Emissions from the facility include PM10, NOx, CO, SO2, and HAPs. This modeling is part of a modified
approval order. The emission rates for NOx and PM10 triggered the requirement to model under R307-410.
Modeling was performed by the applicant.
The results of the modeling are as follows:
PM10: total impact of 135.8 µg/m3. This is 90.5% of the NAAQS
NOx: total impact of 142.3 µg/m3. This is 75.7% of the NAAQS
The following suggested permit language is included under the Terms and Conditions in the AO:
1. Emergency generator engine testing shall be limited to no more than two engines at the same time.
2. Emergency generator engine testing shall only occur between the hours of 7:00 am and 7:00 pm.
3. Each of the emergency generators shall have a stack height of no less than 42 feet as measured from the
ground. The office emergency generator shall have a stack height of no less than 9.1 feet as measured from the
ground.
4. Each natural gas-fired generator shall have a stack height of no less than 29.9 feet as measured from the
ground. [Last updated November 5, 2024]
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 4
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)
Ammonia 61.01
CO2 Equivalent 993969 997261.00
Carbon Monoxide 196.54 202.72
Nitrogen Oxides 43.87 51.28
Particulate Matter - PM10 30.42 30.87
Particulate Matter - PM2.5 30.42 30.87
Sulfur Dioxide 15.22 15.26
Volatile Organic Compounds 46.75 48.28
Hazardous Air Pollutant Change (lbs/yr)Total (lbs/yr)
1,3-Butadiene (CAS #106990)4540 4540
1-METHYLNAPHTHALENE (CAS #90120)560 560
2,2,4-Trimethylpentane (CAS #540841)4260 4260
Acrolein (CAS #107028)3500 3500
Benzene (Including Benzene From Gasoline) (CAS #71432)7429 7500
Biphenyl (CAS #92524)3620 3620
Ethyl Benzene (CAS #100414)680 680
Formaldehyde (CAS #50000)46360 46360
Generic HAPs (CAS #GHAPS)6438 6460
Hexane (CAS #110543)18865 18900
Methanol (CAS #67561)1700 1700
Naphthalene (CAS #91203)1260 1260
PAH, Total (CAS #234)460 460
Styrene (CAS #100425)400 400
Toluene (CAS #108883)6698 6940
Xylenes (Isomers And Mixture) (CAS #1330207)2590 3140
Change (TPY)Total (TPY)
Total HAPs 54.70 55.16
Note: Change in emissions indicates the difference between previous AO and proposed modification.
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 5
Review of BACT for New/Modified Emission Units
1.BACT review regarding updated diesel-fired generators
Although there are several changes in the final installed diesel-fired emergency engines, the
proposed project for these changes was submitted under the auspices of R307-401-12 Reduction of
Air Pollutants. This exemption allows the source to make equipment changes at a facility so long
as emissions of no regulated pollutant increase. The rule exempts the source from the
requirements of R307-401-5 through R307-401-8. The requirements of application of BACT are
found in R307-401-5(2)(b) and R307-401-8(1)(a). Thus no BACT review is required for the
updated diesel-fired engines. However, the source has opted to install the equivalent control
equipment and techniques as originally determined to represent BACT for this type of equipment -
specifically the use of ultra-low sulfur diesel (ULSD) as fuel, and integrated SCR. [Last updated
November 5, 2024]
2.BACT review regarding updated diesel fuel storage tanks
As with the diesel-fired emergency engines, the number and size of associated diesel fuel storage
tanks are also being updated. These changes were also submitted under R307-401-12 - Reduction
of Air Pollutants. As previously discussed, this exempts these changes from being subject to
BACT review. Again, the source has elected to follow the original control requirements.
Emissions from the storage tanks are mostly VOCs. The tanks have drop tubes equipped to allow
for submerged filling. Submerged filling reduces emissions in tank loading operations and is
considered best practice. In addition, the source will conduct manufacturer recommended
maintenance and testing. [Last updated November 5, 2024]
3.BACT review regarding new natural gas-fired generators
The Novva site has requested to operate 72, identical, 4601 bhp, natural gas RICE, which utilize
lean burn combustion methods to deliver prime power to its data center. The source submitted the
following as proposed BACT for these engines:
NOx Emissions
The following technically feasible control technologies are proposed to achieve BACT for NOx
emissions in natural gas reciprocating generator engines:
Routine Maintenance
Good Combustion Practices
SCR
Low NOx Technology
This combination of technologies allowed Novva to propose an emission rate of 0.0152 g/bhp-hr
(0.15 lb/hr). as BACT
CO Emissions
Novva has proposed routine maintenance/good combustion practices along with the use of an
oxidation catalyst. Novva proposed an emission rate of 0.065 g/bhp-hr (0.63 lb/hr) bas BACT.
VOC Emissions
As VOC emissions can be controlled using the same methods as controlling CO emissions, Novva
has proposed the use of routine maintenance/good combustion practices and oxidation catalyst. An
emission rate of 0.00608 g/bhp-hr (0.06 lb/hr) is proposed as BACT.
Particulate (PM10 and PM2.5) Emissions
Engineer Review N160660003: Novva SLC Common, LLC.
November 5, 2024
Page 6
Control of particulate emissions from natural gas-fired engine generators is limited to good
combustion practices/routine maintenance and the use of low-sulfur natural gas as fuel. No other
addon controls have been determined to be economically or technically feasible for reducing
particulate emissions. Novva has proposed the use of good combustion practices/routine
maintenance and the use of low-sulfur natural gas as fuel as BACT.
SO2 Emissions
SO2 emissions in combustion equipment are directly related to the level of sulfur present in the
supplied fuel. For natural gas-fired equipment the level of sulfur is inherently quite low. Alongside
good combustion practices and routine maintenance, the use of low-sulfur natural gas represents
BACT. Novva has proposed the use of good combustion practices/routine maintenance and the use
of low-sulfur natural gas as fuel as BACT.
Ammonia Emissions:
Within the Salt Lake City PM2.5 Nonattainment Area, ammonia is defined as a precursor pollutant
towards the formation of PM2.5. Thus, ammonia emissions are also subject to BACT. Ammonia
emissions from these units are the result of ammonia slip from the SCR controls. The only control
method currently established for the minimization of these emissions is the use of Programable
Logic Controllers (PLC). The PLCs are designed to measure the NOx and ammonia emission rates
as a process monitor in real time and then adjust the ammonia injection rate accordingly to
maximize control of NOx while minimizing ammonia slip. Novva has proposed the use of PLCs
with the SCR control technology as BACT.
[Last updated November 5, 2024]
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 five (5) years. [R307-401-8]
Engineer Review N160660003: Novva SLC Common, LLC.
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Page 7
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):
II.A THE APPROVED EQUIPMENT
II.A.1 West Jordan Data Center
II.A.2
NEW
Natural Gas-Fired Generator Engines
Seventy-two (72) Jenbacher Model: JGS 620 J715
Rating: 3271.8 kW (4,601 hp)
Control: SCR and Oxidation Catalyst
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ
II.A.3 Diesel-fired Emergency Generator Engines
Seventeen (17) MTU 1500
Rating: 1,736 kW (2,328 hp) each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
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Page 8
II.A.4 Diesel-fired Emergency Generator Engine
Cat C15 (Office)
Rating: 568 kW (762 HP)
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.5
NEW
Diesel-fired Emergency Generator Engines
Eleven (11) Kohler (KD 2500)
Rating: 2,700 kW (3,621 HP) each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.6
NEW
Diesel-fired Emergency Generator Engines
Four (4) Cummins 2000
Rating: 2,179 kW (2,922 HP) each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.7
NEW
Diesel-fired Emergency Generator Engines
Two (2) MTU 1750
Rating: 1,910 kW (2,561 HP) each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.8
NEW
Diesel-fired Emergency Generator Engines
Two (2) MTU 2000
Rating: 2,279 kW (3056 HP) each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.9 Eleven (11) Bulk Diesel Storage Tanks
Contents: ULSD
Capacity (gallons): 8,000
II.A.10 Four (4) Diesel Belly Tank
Contents: ULSD
Capacity (gallons): 3,650
II.A.11 Thirty-two (32) Diesel Day Tanks
Contents: ULSD
Capacity (gallons): 400
II.A.12 Boiler
Rating: <5 MMBtu/hr
Fuel: Natural Gas
NSPS/MACT Applicability: 40 CFR 63 Subpart DDDDD
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November 5, 2024
Page 9
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
Natural Gas Generator Engine Requirements
II.B.1.a
NEW
The owner/operator shall certify that each natural gas-fired engine installed on site emits at no
greater than the following controlled emission rates:
1. NOx: 0.0152 g/bhp-hr (0.15 lb/hr)
2. CO: 0.065 g/bhp-hr (0.63 lb/hr)
3. VOC: 0.00608 g/bhp-hr (0.06 lb/hr). [R307-401-8]
II.B.1.a.1
NEW
To demonstrate compliance with these emission rates, the owner/operator shall test each
engine as per the requirements of 40 CFR 60 Subpart JJJJ. [40 CFR 60 Subpart JJJJ, R307-
401-8]
II.B.1.b
NEW
The owner/operator shall combust only pipeline quality natural gas as fuel in each natural gas-
fired engine. [R307-401-8]
II.B.1.c
NEW
The exhaust stack height for each natural gas-fired generator engine shall be no less than 29.9
feet (9.1 meters) as measured from the ground. [R307-401-8]
II.B.2 Emergency Generator Engine Requirements
II.B.2.a
NEW
The owner/operator shall certify that each emergency engine installed on site has a controlled
(i.e., accounting for SCR) NOx emission rate of no greater than the specified NOx emission
rate for that engine model at the exhaust point:
CAT C15: 4.61 lb/hr
Cummins 2000: 8.84 lb/hr
MTU 1500 Miratech: 7.33 lb/hr
MTU 1500 SafetyPower: 8.32 lb/hr
MTU 1750: 8.45 lb/hr
MTU 2000: 8.54 lb/hr
Kohler 2500: 15.67 lb/hr. [R307-401-8]
II.B.2.a.1
NEW
To demonstrate compliance with the emission rate, the owner/operator shall test each engine
as outlined in 40 CFR 60 Subpart IIII. [40 CFR 60 Subpart IIII, R307-401-8]
II.B.2.b
NEW
The owner/operator shall not operate each emergency engine on site for more than 42 hours
per rolling 12-month period during non-emergency situations. There is no time limit on the
use of the engines during emergencies. [40 CFR 60 Subpart ZZZZ, R307-401-8]
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Page 10
II.B.2.b.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
[R307-401-8, 40 CFR 63 Subpart ZZZZ]
II.B.2.b.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [R307-401-8, 40 CFR 63 Subpart ZZZZ]
II.B.2.c
NEW
The owner/operator shall perform maintenance and testing of the emergency generator
engines in accordance with the following:
A. The owner/operator shall not operate more than two (2) emergency generator engines at
one time for maintenance and testing operations
B. Each emergency generator shall only be tested between the hours of 7:00 a.m. and 7:00
p.m. [R307-410]
II.B.2.c.1
NEW
The owner/operator shall:
A. Record the date and time that the maintenance and testing was performed;
B. Record the emergency generator engine that was maintained and tested;
C. Maintain records of maintenance and testing. [R307-401-8]
II.B.2.d
NEW
The exhaust stack height for the CAT C15 (office) emergency generator engine shall be no
less than 9.1 feet (2.8 meters) as measured from the ground.
The exhaust stack height for all other emergency generator engines (except the CAT C15
emergency generator) shall be no less than 42 feet (12.8 meters) as measured from the ground.
[R307-401-8]
II.B.2.e 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.e.1
NEW
The owner/operator shall only combust diesel fuel that meets the definition in 40 CFR
1090.305 of ultra-low sulfur diesel (ULSD), which has a sulfur content of 15 ppm or less.
[R307-401-8]
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Page 11
II.B.2.e.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]
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Page 12
PERMIT HISTORY
When issued, the approval order shall supersede (if a modification) or will be based on the
following documents:
Is Derived From Source Submitted NOI dated May 30, 2024
Incorporates Additional Information Received dated May 30, 2024
Incorporates Additional Information Received dated September 13, 2024
Supersedes DAQE-AN160660001-22 dated February 23, 2022
REVIEWER COMMENTS
1.Comment regarding applicability of federal regulations:
NSPS Subpart A (General Provisions)
All affected sources subject to an NSPS are also subject to the general provisions of NSPS Subpart
A unless specifically excluded by the source-specific NSPS.
NSPS Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels (Including
Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification
Commenced After July 23, 1984, and On or Before October 4, 2023. The provisions of this subpart
are applicable to owners/operators of storage vessels with a capacity greater than or equal to 75
cubic meters that is used to store volatile organic liquids. The storage tanks on site are less than 75
cubic meters; therefore, Subpart Kb does not apply to this source.
NSPS Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines, The provisions of this subpart are applicable to owners/operators of CI ICE
that 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/operator. The engines at this
source will be constructed after these dates. NSPS IIII is applicable to all emergency generator
engines on site.
NSPS Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion
Engines, establishes requirements for stationary spark ignition internal combustion engines for
which construction, modification, or reconstruction commenced after June 12, 2006. The provisions
of this subpart are applicable to owners and operators of spark ignition internal combustion engines
which commenced construction after June 12, 2006 and were manufactured after July 1, 2007. The
construction date is the date the engine was ordered by the owner or operator. The proposed
generator engines will be constructed after the specified construction dates. NSPS JJJJ is applicable
to the generator engines on site.
NESHAP Subpart A (General Provisions)
All affected sources are subject to the general provisions of Part 63 NESHAP Subpart A, unless
specifically excluded by the source-specific NESHAP. These provisions include initial notification
and performance testing, recordkeeping, and monitoring requirements for all other subparts, as
applicable.
NESHAP Subpart ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary
Reciprocating Internal Combustion Engines, applies to stationary RICE at major and area sources of
HAPs. Subpart ZZZZ establishes requirements to demonstrate initial compliance and continuous
compliance with emission limitations and operating limits. The Novva Data Center is currently an
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November 5, 2024
Page 13
area source that will become a major source of HAPs, as the project's HAP emissions are greater
than ten (10) tons per year for an individual HAP, and greater than twenty-five (25) tons per year of
total HAPs. For the purposes of regulatory applicability, the engines associated with the proposed
project are greater than 500 BHP and are four-stroke lean burn (4SLB) engines. Per 40 CFR
63.6590(a)(2)(iii), a stationary RICE at an existing area source of HAPs is new if construction
commenced after June 12, 2006. This subpart applies to this facility, which is considered a new
source under these provisions.
NESHAP Subpart DDDDD, National Emission Standards for Hazardous Air Pollutants for Major
Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters applies to industrial,
commercial, or institutional boilers or process heaters as defined in CFR 63.7575 that is located at,
or is part of, a major source of HAP. NESHAP Subpart DDDDD is applicable to the boiler on site.
[Last updated November 6, 2024]
2.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; and
4. Any Title IV affected source.
Upon completion of this permitting project, this facility will become major for HAP emissions,
having annual emission of 23.18 tons of formaldehyde and total HAP emissions of 55.14 tons
annually. This project also represents a significant increase in CO emissions. Following this project
the source will be reclassified as a major source of CO emissions. Both the HAP emissions and CO
emissions qualify this source as a major source subject to Title V. Following startup of the new
equipment in this project, Novva will have 12 months from the date of startup as a major source to
apply for a Title V Operating Permit. [Last updated November 5, 2024]
3.Comment regarding changes in equipment:
On May 30, 2024, Novva submitted two separate NOIs for changes at its existing West Jordan Data
Center. These projects have been combined into a single permitting action. The first NOI covered
multiple changes in both the diesel-fired emergency engine generators and diesel storage tanks.
These changes were submitted under the exemption provisions of R307-401-12 - Reduction in Air
Pollutants. UDAQ has reviewed the associated emission totals from this portion of the change and
agrees it qualifies under this exemption. The second NOI covered the proposed installation of 72
new natural gas-fired engine generators for primary power production. This change is a major
modification to an existing minor source. Total emission increases from both NOIs taken together
are listed in the Summary of Emissions Table. The increase in CO and HAP emissions qualifies this
source as a major source for CO and HAPs (single and combined) and requires a Title V permit.
[Last updated November 5, 2024]
4.Comment regarding emission calculations:
Emission calculations for this project are based on a combination of engine manufacturer's
specifications, EPA "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-
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November 5, 2024
Page 14
standards/diesel-fuel-standards-and-rulemakings, 40 CFR 98, Table C-1 to Subpart C for Distillate
Fuel Oil No. 2, and supplied BACT emission limitations. All polycyclic aromatic hydrocarbon have
been conservatively included as HAPs and includes naphthalene. HAP pollutant emission factors per
AP-42, Section 3.4 and AP-42 Table 3.2-2.
[Last updated November 5, 2024]
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November 5, 2024
Page 15
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
JJ
JJ

*6
4525 Wasatch Blvd, Ste 200, Salt Lake City, UT 84124 P 801.272.3000 / F 801.272.3040

May 29, 2024
Mr. Alan Humpherys
Utah Department of Environmental Quality
Division of Air Quality
195 North 1950 West
Salt Lake City, Utah 84114
[e-mail]
Subject: Reduction in Emissions - Administrative Amendment Request
Dear Alan,

Novva Data Centers (Novva) submitted a Notice of Intent (NOI) air permit application on June 10, 2021, and an Approval Order (AO) was subsequently issued on February 23, 2022. In the NOI, Novva proposed
installation of forty (40) 2,328 HP emergency generator engines, one (1) 762 HP emergency generator
engine, fifty-one (51) diesel tanks, and one (1) natural gas boiler. Following the submittal of the NOI air permit application to the Utah Division of Air Quality (UDAQ), supply chain issues have required Novva to
search for alternative emergency generators with accompanying diesel storage tanks to meet the
datacenters back up power supply requirements. Of the 40 originally permitted 2,328 HP emergency generator engines, only seventeen (17) were obtained; however, Novva found nineteen (19) suitable
alternatives. Consequently, Novva is proposing to install a total of 37 emergency engines, as opposed to the
41 generators that were included in the submitted NOI. Additionally, after a comprehensive evaluation of the optimal operational parameters for testing and maintenance procedures, Novva has found that they will
not require a full 100 hours per year of operation. Instead, Novva proposes to take a limit on their operation
and use an enforceable limit on sitewide fuel usage, which is shown in Appendix B Table B-52.
Air dispersion modeling has been updated and will be submitted in conjunction with this letter.

Novva is submitting the enclosed request to amend its current approval order (AO) Utah Division of Air
Quality (UDAQ) AO Permit No. DAQE-AN160660001-22, issued February 23, 2022, to account for the
following equipment in Section II.A:

► One (1) 762 HP emergency generator engine;
► Seventeen (17) 2,328 HP emergency generator engines;
► Eleven (11) 3,621 HP emergency generator engines;
► Four (4) 2,922 HP emergency generator engines;
► Two (2) 2,561 HP emergency generator engines;
► Two (2) 3,056 HP emergency generator engines;
► One (1) 500 gallon diesel day tank;
► Thirty-two (32) 400 gallon diesel day tanks;
► Four (4) 3650 gallon diesel day tanks;
► Eleven (11) 8,000 gallon bulk diesel storage tanks; and
► One (1) 2 MMBtu/hr natural gas boiler.

A replacement of AO Section II Table II.A is presented in Attachment A.

Novva Data Centers, West Jordan, Utah – AO DAQE-AN160660001-22 Administrative Amendment
May 29, 2024 Page 2 of 3

Through the implementation of a sitewide fuel usage limit, this project represents a reduction in potential
emissions at the facility. As a result, Novva is providing this notification to the UDAQ under its Reduction In
Emissions Rule, which has been defined in the following paragraphs.

R307-401-12. Reduction in Air Pollutants.
Utah Administrative Code (UAC) R307-401-12, Reduction in Air Pollutants, states that air emission sources
that meet the criteria of the source categories and reduce or eliminate air pollutants are exempt from
approval order (AO) requirements found in R307-401-5 through R307-401-8. UAC R307-401-5 through
R307-401-8 includes the following:

► R307-401-5. Notice of Intent
► R307-401-6. Review Period
► R307-401-7. Public Notice
► R307-401-8. Approval Order

Recognizing that the requested amendments propose to reduce the testing and maintenance operation via
enforceable site wide fuel usage limit, the Potential to Emit will decrease. This does not change the
applicability of any State or Federal regulations. As a result, Novva has documented the following
applicability to R307-401-12.

(1) Applicability. The owner or operator of a stationary source of air pollutants that reduces or eliminates
air pollutants is exempt from the approval order requirements of R307-401-5 through R307-401-8 if:

The following information demonstrates that the criterium of UAC R307-401-12 are met:

(a) the project does not increase the potential to emit of any air pollutant or cause emissions of any new
air contaminant, and
(b) the director is notified of the change and the reduction of air pollutants is made enforceable through an approval order in accordance with (2) below.
(2) Notification. The owner or operator shall submit a written description of the project to the director no
later than 60 days after the changes are made. The director will update the source's approval order or issue a new approval order to include the project and to make the emission reductions enforceable. Public review
under R307-401-7 is not required for the update to the approval order.

Novva meets the requirements of UDAQ’s Reduction in Emissions rule, as discussed in the following:

R307-401-12(1)(a). By taking a limit on their sitewide fuel usage, Novva will achieve a reduction in
emissions. Emission calculations have been provided in Attachment B to demonstrate the reduction in
emissions.

R307-401-12(1)(b). Novva is proposing that UDAQ amend its AO, DAQE-AN160660001-22, through an
administrative amendment for this reduction in emergency generator emissions.

R307-401-12(2). Novva requests that UDAQ accept this letter as its notification to the director of the
changes made at its West Jordan facility for installation of the units listed in Attachment B.

As documented in this notification, the site-wide potential to emit will reduce; therefore, UDAQ’s “Reduction
in Emissions” exemption from modifying its AO applies, and this letter serves as Novva’s notification.

Novva Data Centers, West Jordan, Utah – AO DAQE-AN160660001-22 Administrative Amendment
May 29, 2024 Page 3 of 3

If you have further questions about the administrative amendment, please reach out to Johnathan Price at
Trinity Consultants ([e-mail]) or Brian Mensinger at Trinity Consultants
([e-mail]).

Sincerely,

Steven Boyce
VP Infrastructure Research and Design – Novva

Anthony Gustin
Mission Critical Project Manager – Novva

CC: Johnathan Price, Trinity Consultants
Brian Mensinger, Trinity Consultants
A-1
Attachment A – AO Section II Table II.A Replacement

II.A.I West Jordan Data Center
II.A.2 Seventeen (17) Emergency Generator Engines
Rating: 2,328 HP each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.3 Emergency Generator Engine
Rating: 762 HP
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.4 Eleven (11) Emergency Generator Engines
Rating: 3,621 HP each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.5 Four (4) Emergency Generator Engines
Rating: 2,922 HP each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.6 Two (2) Emergency Generator Engines
Rating: 2,561 HP each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
Novva Data Centers, West Jordan, Utah – AO DAQE-AN160660001-22 Administrative Amendment
May 29, 2024 Page 2 of 3

A-2

II.A.7 Two (2) Emergency Generator Engines
Rating: 3056 HP each
Model Year: 2019
Fuel: Ultra-low Sulfur Diesel (ULSD)
Control: SCR
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.8 Eleven (11) Bulk Diesel Storage Tanks
Contents: ULSD
Capacity (gallons): 8,000

II.A.9 Four (4) Diesel Belly Tanks
Contents: ULSD
Capacity (gallons): 3,650

II.A.10 Thirty-two (32) Diesel Day Tanks
Contents: ULSD
Capacity (gallons): 400

II.A.11 Boiler
Rating: <5 MMBtu/hr
Fuel: Natural Gas

Attachment B – Emission Calculations
Reduction in Emissions
Table B-1. Novva West Jordan Data Center
NOX NO2 CO PM10 PM2.5 SO2 VOC CO2e Total HAPs
CAT C15 (Office) Engine 0.02 0.02 0.02 9.81E-04 9.81E-04 1.05E-04 7.85E-04 18 1.67E-04
MTU 1500 Engines 1.42 1.42 1.40 0.10 0.10 4.89E-03 0.50 816 8.16E-03
MTU 1750 Engines 0.19 0.19 0.21 0.02 0.02 6.00E-04 0.04 106 1.06E-03
MTU 2000 Engines 0.21 0.21 0.36 0.03 0.03 7.13E-04 0.05 127 1.27E-03
Kohler 2500 Engines 1.85 1.85 1.58 0.14 0.14 8.73E-05 0.18 787.27 8.18E-03Cummins 2000 Engines 0.34 0.34 0.13 0.02 0.02 2.56E-05 0.15 235 2.44E-03
Diesel Tanks ------------0.01 --6.77E-03
Natural Gas Boiler 0.86 0.86 0.72 0.07 0.07 5.15E-03 0.05 1,026 5.20E-05
Proposed Revised PTE 4.89 4.89 4.42 0.37 0.37 0.01 0.97 3115.23 0.03
Currently Permitted PTE1 7.41 7.41 6.18 0.45 0.45 0.04 1.53 6,407 0.46
Project Change -2.52 -2.52 -1.76 -0.08 -0.08 -0.03 -0.56 -3291.77 -0.43
Major Source Thresholds2 70 70 250 100 70 70 70 100,000 10/25
Threshold Exceeded? No No No No No No No No No
Modeling Limits3 40 40 100 15 --40 ----See HAP
Summary
Threshold Exceeded?No No No No No No No No No
Unit Group Potential Annual Emissions Estimate (tpy)
1. Currently Permitted PTE is per AO DAQE-AN160660001-22
2. Major source thresholds are defined by 40 CFR section 51.165(a)(1)(iv)(A).
3. Modeling Limit is stated in UDAQ Emissions Impact Assessment Guidelines under Table 1: Total Controlled Emission Rates for New Sources or Emissions Increase.
Novva SLC Common, LLC.Trinity Consultants 1 of 22
Reduction in Emissions
Table B-2. Haps Summary Table
Pollutant Proposed PTE (tpy)Currently Permitted
PTE (tpy)1 Project Change (tpy)
2-Methylnaphthalene 2.06E-07 2.60E-07 0.00
3-Methylchloranthrene 1.55E-08 1.55E-08 0.00
7,12-Dimethylbenz(a)anthracene 1.37E-07 1.37E-07 0.00
Acenaphthene 1.55E-08 1.55E-08 0.00
Acenaphthylene 1.55E-08 1.55E-08 0.00
Acetaldehyde 3.60E-04 8.28E-04 0.00
Acrolein 1.12E-04 2.59E-04 -1.47E-04
Anthracene 2.06E-08 2.06E-08 0.00
Benz(a)anthracene 1.55E-08 1.55E-08 0.00
Benzene 1.13E-02 3.54E-02 -2.41E-02
Benzo(a)pyrene 1.03E-08 1.03E-08 0.00
Benzo(b)fluoranthene 1.55E-08 1.55E-08 0.00
Benzo(g,h,i)perylene 1.03E-08 1.03E-08 0.00
Benzo(k)fluoranthene 1.55E-08 1.55E-08 0.00
Chrysene 1.55E-08 1.55E-08 0.00
Dibenzo(a,h)anthracene 1.03E-08 1.03E-08 0.00
Dichlorobenzene 1.03E-05 1.03E-08 0.00
Ethylbenzene 2.31E-04 1.42E-02 -0.01
Fluoranthene 2.58E-08 2.58E-08 0.00
Fluorene 2.40E-08 2.40E-08 0.00
Formaldehyde 1.77E-03 3.24E-03 -1.47E-03
Hexane 1.55E-02 1.75E-02 -2.01E-03
Indeno(1,2,3-cd)pyrene 1.55E-08 1.55E-08 0.00
Naphthalene 1.88E-03 1.89E-03 -1.50E-05
PAH 0.00 6.97E-03 -0.01
Phenanathrene 1.46E-07 1.46E-07 0.00
Pyrene 4.29E-08 4.29E-08 0.00
Toluene 5.89E-03 1.21E-01 -0.12
Xylenes 7.22E-03 2.75E-01 -0.27
Arsenic Compounds 1.72E-06 1.72E-06 0.00
Beryllium Compounds 1.03E-07 1.03E-07 0.00
Cadmium Compounds 9.45E-06 9.45E-06 0.00
Chromium Compounds 1.20E-05 1.20E-05 0.00
Cobalt Compounds 7.21E-07 7.21E-07 0.00
Lead Compounds 4.29E-06 4.29E-06 0.00
Manganese Compounds 3.26E-06 3.26E-06 0.00
Mercury Compounds 2.23E-06 2.23E-06 0.00
Nickel Compounds 1.80E-05 1.80E-05 0.00
Selenium Compounds 2.06E-07 2.06E-07 0.00
1. Currently Permitted PTE is per AO DAQE-AN160660001-22
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Table B-3. Engine Parameters
Engine
CAT (Office)
Engine Model Number CAT C15 In-line 6, 4-
cycle diesel
Annual Hours of Operation (hr/yr)2 42
Total Number of Engines 1
Maximum Number Engines Operating at a
given time 1
Engine Maximum Power Output - 100% Load
(kWm)568
Engine Maximum Power Output - 100% Load
(hp)762
Maximum Fuel Consumption per Engine
(gal/hr)90.0
Brake-specific fuel consumption (Btu/hp-hr)3 7,000
Fuel Type Diesel
Fuel Sulfur Content (%)4 0.0015
2. Inclusive of hours testing and maintenance.
4. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings
Table B-4. Office Engine - Criteria Pollutant Engine Emission Factors - 100% load
Uncontrolled1 Controlled1 Units
NOx 3.68 0.368375737 g/kW-hr
CO 0.87 0.87 g/kW-hr
HC/VOC2 0.03 0.03 g/kW-hrPM/PM10/PM2.53 0.04 0.04 g/kW-hr
SO2 4.00E-03 4.00E-03 g/kW-hr
1. Emission factors engine spec sheet, Rated Speed Potential Site Variation.
2. It is conservatively assumed that HC=VOC.
3. It is conservatively assumed that PM=PM10=PM2.5.
Table B-5. Start up Parameters (SCR - NO X only)
Parameter Value Units
Total Annual Startups per Engine1 12 startup/yr
Uncontrolled Operating Time2 30 min/startup
Total Annual Uncontrolled Operating Time 6 hr/yr
1. Per design basis, each engine will be shutdown once a month for maintenance. It follows that there should be 1 startup/month or 12 startups/yr per engine
2. Uncontrolled startup time per client email
Table B-6. MTU Criteria Pollutant Potential to Emit - Start Up Operation
Emission Rate
(lb/hr)
NOx 1.50
Table B-7. Controlled Criteria Pollutant Potential to Emit - Normal Operation
(tpy)
NOx 0.02CO0.02
VOC 7.85E-04
PM10 9.81E-04
PM2.5 9.81E-04
SO2 1.05E-04
Parameter1
1. Unless otherwise noted, engine parameters per engine manufacture's spec sheet.
3. Per 40 CFR 98, Table C–1 to Subpart C for Distillate Fuel Oil No. 2.
Emission FactorsPollutant
Pollutant
Pollutant
Potential
Emissions
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Table B-8. Greenhouse Gas Potential to Emit
CO2 1 73.96 18.26
CH4 25 3.00E-03 7.41E-04N2O2986.00E-04 1.48E-04
18
Table B-9. HAP Potential to Emit
(lb/hr)3 (tpy)
Benzene 7.76E-04 4.14E-03 8.69E-05
Toluene 2.81E-04 1.50E-03 3.15E-05
Xylenes 1.93E-04 1.03E-03 2.16E-05
Formaldehyde 7.89E-05 4.21E-04 8.84E-06
Acetaldehyde 2.52E-05 1.34E-04 2.82E-06
Acrolein 7.88E-06 4.20E-05 8.83E-07
Napthalene 1.30E-04 6.93E-04 1.46E-05
1.67E-04
1. All polycyclic aromatic hydrocarbon have been conservatively included as HAPs and includes naphthalene.
2. HAP pollutant emission factors per AP-42, Section 3.4 Large Stationary Diesel Engines (> 600 hp), October 1996.
3. Hourly emissions are conservatively based on one hour of operation of a signle MTU engine.
Emission
(tpy)Pollutant Global Warming
Potential1
Emission Factor
(kg/MMBtu)2
Total HAPs
Total CO2e Emissions
1. Global Warming Potentials are obtained from Subpart A of 40 CFR 98, Table A–1 "Global Warming Potentials."
2. Emission factor for carbon dioxide is obtained from 40 CFR 98, Table C–1 to Subpart C for Distillate Fuel Oil No. 2. Emission factors for

Pollutant1 Emission Factor2
(lb/MMBtu)
Emissions
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Table B-10. Generator Information
Number of Engines Engine Manufacturer Engine Model Tier Generator Electrical Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating
Hours per Unit1 Fuel Type Fuel Sulfer
Content (%)2
2 MTU 12V4000 Tier 4 Compliant 1,750 2,561 42 Diesel 0.0015%
1. Testing, maintenance, and repair hours:42 hrs/yr2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.
Table B-11. Emissions Parameters CO NOX PM VOC SO2
100%1,910 2,561 123 17 5,166 713 5.52 33.81 3.03E-01 5.90E-01 0.0275%1,432 1,920 93 13 3,906 539 3.76 21.88 3.38E-01 8.21E-01 0.0150%955 1,281 65 9 2,730 377 3.14 12.17 3.90E-01 9.05E-01 8.42E-0325%477 640 65 9 2,730 377 2.32 5.67 1.88E-01 1.37E+00 5.26E-0310%191 256 65 9 2,730 377 3.08 6.58 7.72E-01 2.27 2.95E-03123175,166 713 5.52 33.81 7.72E-01 2.27 0.02
Table B-12. Emissions ControlsPercent Load 100%75%50%25%10%NOX Control Efficiency (%)1 90.00%90.00%90.00%90.00%0.00%
SCR warmup time (minutes)1 10.00 13.00 17.00 26.00 -
1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-13. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr)
Emissions 25% with SCR (lb/hr)
Emissions 10% without SCR (lb/hr)
Emissions 10% with SCR (lb/hr) PM/PM10/PM2.51 0.30 0.30 0.34 0.34 0.39 0.39 0.19 0.19 0.77 0.77
NOX 33.81 3.38 21.88 2.19 12.17 1.22 5.67 0.57 6.58 0.66
VOC2 0.59 0.59 0.82 0.82 0.91 0.91 1.37 1.37 2.27 2.27CO5.52 5.52 3.76 3.76 3.14 3.14 2.32 2.32 3.08 3.08SO20.02 0.02 0.01 0.01 8.42E-03 8.42E-03 5.26E-03 5.26E-03 2.95E-03 2.95E-03
CO23 2,768 2,768 2,093 2,093 1,463 1,463 1462.59 1462.59 1462.59 1462.59
CH43 0.11 0.11 0.08 0.08 0.06 0.06 0.06 0.06 0.06 0.06
N2O3 0.02 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.01
CO2e4 2,777 2,777 2,100 2,100 1,468 1,468 1467.61 1467.61 1467.61 1467.61
1. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.
2. It is conservatively assumed that hydro-carbons (HC) are equivalent to the emission VOCs.3. Emission factors from 40 CFR 98 Tables C-1 and C-2.
73.96 CO23.00E-03 CH46.00E-04 N2O4. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-14. Start up Parameters - Per EngineParameter Value Units100% load ramp up time 10.00 minutes75% load ramp up time 13.00 minutes50% load ramp up time 17.00 minutes25% load ramp up time 26.00 minutes
No load tests per year1 12 runs/yrAnnual no load test 1 runs/yr
Annual load bank tests per year1 1 runs/yr
Monthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yrAnnual test - run time at 35% load (assumed ~25%)3 30 min/runAnnual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 123.00100% load time with SCR4 32.17 hr/yr 3,956.50100% load time without SCR 0.83 hr/yr 102.5050% load time without SCR 0.00 hr/yr 0.0050% load time with SCR4 0.50 hr/yr 32.5025% load time without SCR4 0.43 hr/yr 28.1725% load time with SCR4 0.07 hr/yr 4.330% load time without SCR5 7.00 hr/yr 455.00Total hours 42 hr/yr 4,702.00
6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
Associated Fuel Use (gal/yr)
Uncontrolled Emission Factors
lb/hr
Max
Power(bhp)Percent Load Power (kW)Fuel Usage(gal/hr)Fuel Usage(MMBtu/hr)Fuel Usage (gal/yr)Fuel Usage (MMBtu/yr)
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.
3. Annual load bank testing consists of 35% load for 30 min, followed by 55% load for 30 min, and then 85% load for 60 minutes.2. No load testing is assumed to be at 10% load as emissions data is not available at 0% load.
4. All time not specified for testing is assumed to be run at 100% load.5. Monthly testing at 0% load for 30 minutes plus one (1) annual 1-hour no load test.
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Table B-15. Criteria Pollutant and GHG Potential to Emit
Max (lb/hr)(tpy)Max (lb/hr)(tpy)PM 0.30 8.00E-03 0.61 0.02
NOx 33.81 0.09 67.63 0.19VOC0.59 0.02 1.18 0.04CO5.52 0.11 11.03 0.21
SO2 0.02 3.00E-04 0.03 0.00
CO2 2,768 52.90 5535.35 105.80CH40.11 2.15E-03 0.22 0.00N2O0.02 4.29E-04 0.04 8.58E-04CO2e2,777 53.08 5554.35 106.16
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)(lb/hr)(tpy)Benzene 7.76E-04 1.32E-02 2.77E-04 2.63E-02 5.53E-04Toluene2.81E-04 4.77E-03 1.00E-04 9.54E-03 2.00E-04Xylenes1.93E-04 3.28E-03 6.88E-05 6.55E-03 1.38E-04Formaldehyde7.89E-05 1.34E-03 2.81E-05 2.68E-03 5.62E-05Acetaldehyde2.52E-05 4.28E-04 8.98E-06 8.55E-04 1.80E-05Acrolein7.88E-06 1.34E-04 2.81E-06 2.68E-04 5.62E-06Naphthalene1.30E-04 2.21E-03 4.63E-05 4.41E-03 9.27E-051.32E-02 2.77E-04 2.63E-02 5.53E-042.53E-02 5.32E-04 5.06E-02 1.06E-03Max HAPTotal HAP1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
Pollutant Potential to Emit per Engine Total Potential to Emit
Total Potential Emissions for All EnginesPotential Emissions per Engine
Table B-16. Engine HAPs Emissions
Pollutant
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Table B-17. Generator Engine Information
Number of Generator Engines Engine Manufacturer Engine Model Tier3 Generator Electrical Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating Hours per Unit1 Fuel Type Fuel Sulfer Content (%)2
1 Rolls Royce MTU 12V4000G74S Tier 4 Equivalent 1,500 2,328 42 Diesel 0.0015%
1 .Testing, maintenance, and repair hours.42hrs/yr2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.
3. Tier 4 Equivalent rating is achieved via EPA Tier 2 Emission Rating paried with SCR control.
Table B-18. Emissions Parameters
Power CO NOX PM VOC SO2(bhp)100%1,736 2,328 111 15 4,662 643 4.21 33.30 0.27 1.22 0.0275%1,302 1,746 85 12 3,583 494 3.16 20.38 0.34 1.26 0.0150%868 1,164 60 8 2,503 345 2.10 10.91 0.19 1.51 0.0125%434 582 60 8 2,503 345 2.68 4.50 0.33 2.14 0.01MAX111154,662 643 4.21 33.30 3.44E-01 2.14E+00 0.02
Table B-19. Emissions ControlsPercent Load 100%75%50%25%10%NOX Control Efficiency (%)1 90.0%90.0%90.0%90.0%0.0%
SCR warmup time (minutes)1 10.00 13.00 18.00 27.00 -1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-20. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr)
Emissions 25% with SCR (lb/hr) PM/PM10/PM251 0.27 0.27 0.34 0.34 0.19 0.19 0.33 0.33
NOX 33.30 3.33 20.38 2.04 10.91 1.09 4.50 0.45VOC21.22 1.22 1.26 1.26 1.51 1.51 2.14 2.14
CO 4.21 4.21 3.16 3.16 2.10 2.10 2.68 2.68SO2 (lb/hr)3 1.53E-02 1.53E-02 1.15E-02 1.15E-02 9.57E-03 9.57E-03 6.70E-03 6.70E-03
CO24 2.50E+03 2.50E+03 1.92E+03 1.92E+03 1.34E+03 1.34E+03 1.34E+03 1.34E+03
CH44 1.01E-01 1.01E-01 7.79E-02 7.79E-02 5.44E-02 5.44E-02 5.44E-02 5.44E-02N2O42.03E-02 2.03E-02 1.56E-02 1.56E-02 1.09E-02 1.09E-02 1.09E-02 1.09E-02
CO2e5 2.51E+03 2.51E+03 1.93E+03 1.93E+03 1.35E+03 1.35E+03 1.35E+03 1.35E+03
3. SO2 emissions using equation from AP-42 Table 3.4-1 footnote d: 8.09E-03*S1
8.09E-03
73.96 CO2
3.00E-03 CH4
6.00E-04 N2O
1 CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-21. Start up Parameters - Per EngineParameter Value Units100% load ramp up time 10.00 minutes75% load ramp up time 13.00 minutes50% load ramp up time 18.00 minutes25% load ramp up time 27.00 minutesNo load tests per year1 12 runs/yrAnnual no load test 1 runs/yr
Annual load bank tests per year1 1 runs/yr
Monthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yrAnnual test - run time at 35% load (assumed ~25%)3 30 min/runAnnual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 111.00100% load time with SCR4 32.17 hr/yr 3,570.50100% load time without SCR 0.83 hr/yr 92.50
50% load time without SCR 0.0 hr/yr 0.0050% load time with SCR4 0.50 hr/yr 29.8025% load time without SCR4 0.45 hr/yr 26.82
25% load time with SCR4 0.05 hr/yr 2.980% load time without SCR5 7.00 hr/yr 417.20Total hours 42 hr/yr 4,250.80
6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
Uncontrolled Emission Factors
Percent Load Power (kW)
Fuel Usage(gal/hr)Fuel Usage(MMBtu/hr)Fuel Usage (gal/yr)Fuel Usage (MMBtu/yr)lb/hr
1. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.2. It is conservatively assumed that hydro-carbons (HC) are equivalent to the emission VOCs.
4. Emission factors from 40 CFR 98 Tables C-1 and C-2.
5. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.2. No load testing is assumed to be at 25% load as emissions data is not available at 0% load.
3. Annual load bank testing consists of 35% load for 30 min, followed by 55% load for 30 min, and then 85% load for 60 minutes.4. All time not specified for testing is assumed to be run at 100% load.5. Monthly testing at 0% load for 30 minutes plus one (1) annual 1-hour no load test.
Associated Fuel Use (gal/yr)
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Table B-22. Criteria Pollutant and GHG Potential to Emit
Max (lb/hr)(tpy)PM 0.27 5.86E-03NOx33.30 0.09VOC1.22 0.03CO4.21 0.08SO20.02 2.88E-04CO22,498 48CH40.10 1.94E-03N2O0.02 3.88E-04CO2e2,506 48
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)Benzene 7.76E-04 1.19E-02 2.50E-04Toluene2.81E-04 4.30E-03 9.04E-05Xylenes1.93E-04 2.96E-03 6.21E-05Formaldehyde7.89E-05 1.21E-03 2.54E-05Acetaldehyde2.52E-05 3.86E-04 8.11E-06Acrolein7.88E-06 1.21E-04 2.53E-06Naphthalene1.30E-04 1.99E-03 4.18E-051.19E-02 2.50E-042.29E-02 4.80E-04
Pollutant
Table B-23. Engine HAPs Emissions
Max HAPTotal HAP1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
Pollutant Total Potential to Emit
Total Potential Emissions
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Table B-24. Generator Engine Information
Number of Generator Engines Engine Manufacturer Engine Model Tier3 Generator Electrical Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating Hours per Unit1 Fuel Type Fuel Sulfer Content (%)2
16 Rolls Royce MTU 12V4000G74S Tier 4 Equivalent 1,500 2,328 42 Diesel 0.0015%1. Testing, maintenance, and repair hours.42 hrs/yr
2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.3. Tier 4 Equivalent rating is achieved via EPA Tier 2 Emission Rating paried with SCR control.
Table B-25. Emissions Parameters
Power CO NOX PM VOC SO2(bhp)
100%1,736 2,328 111 15 4,662 643 4.21 33.30 0.27 1.22 0.0275%1,302 1,746 85 12 3,583 494 3.16 20.38 0.34 1.26 0.0150%868 1,164 60 8 2,503 345 2.10 10.91 0.19 1.51 0.0125%434 582 60 8 2,503 345 2.68 4.50 0.33 2.14 0.01MAX111154,662 643 4.21 33.30 3.44E-01 2.14E+00 0.02
Table B-26. Emissions ControlsPercent Load 100%75%50%25%10%
NOX Control Efficiency (%)1 90.0%90.0%90.0%90.0%0.0%
SCR warmup time (minutes)1 10.00 13.00 18.00 27.00 -
1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-27. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr)
Emissions 25% with SCR (lb/hr) PM/PM10/PM2.51 0.27 0.27 0.34 0.34 0.19 0.19 0.33 0.33
NOX 33.30 3.33 20.38 2.04 10.91 1.09 4.50 0.45
VOC2 1.22 1.22 1.26 1.26 1.51 1.51 2.14 2.14CO4.21 4.21 3.16 3.16 2.10 2.10 2.68 2.68SO2 (lb/hr)3 1.53E-02 1.53E-02 1.15E-02 1.15E-02 9.57E-03 9.57E-03 6.70E-03 6.70E-03
CO24 2.50E+03 2.50E+03 1.92E+03 1.92E+03 1.34E+03 1.34E+03 1.34E+03 1.34E+03
CH44 1.01E-01 1.01E-01 7.79E-02 7.79E-02 5.44E-02 5.44E-02 5.44E-02 5.44E-02
N2O4 2.03E-02 2.03E-02 1.56E-02 1.56E-02 1.09E-02 1.09E-02 1.09E-02 1.09E-02
CO2e5 2.51E+03 2.51E+03 1.93E+03 1.93E+03 1.35E+03 1.35E+03 1.35E+03 1.35E+03
3. SO2 emissions using equation from AP-42 Table 3.4-1 footnote d: 8.09E-03*S1
8.09E-03
73.96 CO2
3.00E-03 CH4
6.00E-04 N2O
1 CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-28. Start up Parameters - Per Engine
Parameter Value Units100% load ramp up time 8.00 minutes75% load ramp up time 10.00 minutes50% load ramp up time 15.00 minutes25% load ramp up time 20.00 minutesNo load tests per year1 12 runs/yr
Annual no load test 1 runs/yrAnnual load bank tests per year1 1 runs/yr
Monthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yrAnnual test - run time at 35% load (assumed ~25%)3 30 min/run
Annual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 111.00100% load time with SCR4 32.33 hr/yr 3,589.00
100% load time without SCR 0.67 hr/yr 74.00
50% load time without SCR 0.00 hr/yr 0.00
50% load time with SCR4 0.50 hr/yr 29.80
25% load time without SCR4 0.33 hr/yr 19.87
25% load time with SCR4 0.17 hr/yr 9.930% load time without SCR5 7.00 hr/yr 417.20Total hours 42 hr/yr 4,250.80
6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
4. Emission factors from 40 CFR 98 Tables C-1 and C-2.
5. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.
2. No load testing is assumed to be at 10% load as emissions data is not available at 0% load.
Fuel Usage
(MMBtu/yr)lb/hr
Associated Fuel Use (gal/yr)
Uncontrolled Emission Factors
1. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.2. It is conservatively assumed that hydro-carbons (HC) are equivalent to the emission VOCs.
Percent Load Power (kW)
Fuel Usage
(gal/hr)
Fuel Usage
(MMBtu/hr)Fuel Usage (gal/yr)
3. Annual load bank testing consists of 35% load for 30 min, followed by 55% load for 30 min, and then 85% load for 60 minutes.
4. All time not specified for testing is assumed to be run at 100% load.5. Monthly testing at 0% load for 30 minutes plus one (1) annual 1-hour no load test.
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Table B-29. Criteria Pollutant and GHG Potential to Emit
(lb/hr)(tpy)(lb/hr)(tpy)PM 0.27 5.86E-03 4.29 0.09
NOx 33.30 8.34E-02 532.75 1.33VOC1.22 0.03 19.60 0.47CO4.21 0.08 67.36 1.31SO20.02 2.88E-04 0.24 0.00
CO2 2,498 48 39962.55 765.19CH40.10 1.94E-03 1.62 0.03N2O0.02 3.88E-04 0.32 0.01CO2e2,506 48 40099.69 767.82
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)(lb/hr)(tpy)Benzene 7.76E-04 1.19E-02 2.50E-04 1.90E-01 3.99E-03Toluene2.81E-04 4.30E-03 9.04E-05 6.89E-02 1.45E-03Xylenes1.93E-04 2.96E-03 6.21E-05 4.73E-02 9.93E-04Formaldehyde7.89E-05 1.21E-03 2.54E-05 1.93E-02 4.06E-04Acetaldehyde2.52E-05 3.86E-04 8.11E-06 6.18E-03 1.30E-04Acrolein7.88E-06 1.21E-04 2.53E-06 1.93E-03 4.06E-05Naphthalene1.30E-04 1.99E-03 4.18E-05 3.19E-02 6.69E-041.19E-02 2.50E-04 1.90E-01 3.99E-032.29E-02 4.80E-04 3.66E-01 7.68E-03
Max HAPTotal HAP
1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
Pollutant Potential to Emit per Engine Total Potential to Emit
Table B-30. Engine HAPs Emissions
Pollutant Total Potential Emissions for All EnginesPotential Emissions per Engine
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Table B-31. Generator Information
Number of Engines Engine Manufacturer Engine Model Tier Generator Electrical Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating
Hours per Unit1 Fuel Type Fuel Sulfer
Content (%)2
2 MTU 16V4000G74S Tier 4 Compliant 2,000 3,056 42 Diesel 0.0015%
1. Testing, maintenance, and repair hours:42 hrs/yr2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.
Table B-32. Emissions Parameters CO NOX PM VOC SO2
100%2,279 3,056 147 20 6,187 854 9.55 36.33 0.58 0.90 0.0275%1,709 2,292 113 16 4,729 653 6.37 24.41 0.71 0.87 0.0250%1,138 1,526 79 11 3,314 457 2.33 12.82 0.24 1.13 0.0125%569 763 79 11 3,314 457 3.10 5.53 0.40 1.56 6.27E-0310%228 306 79 11 3,314 457 4.88 8.33 0.84 2.45 3.02E-03147206,187 854 9.55 36.33 8.37E-01 2.45 0.02
Table B-33. Emissions ControlsPercent Load 100%75%50%25%10%NOX Control Efficiency (%)1 90.0%90.0%90.0%90.0%0.0%
SCR warmup time (minutes)1 9.00 11.00 15.00 22.00 -1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-34. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr)
Emissions 25%
with SCR (lb/hr)
Emissions
10% without SCR (lb/hr)
Emissions
10% with SCR (lb/hr) PM/PM10/PM2.51 0.58 0.58 0.71 0.71 0.24 0.24 0.40 0.40 0.84 0.84
NOX 36.33 3.63 24.41 2.44 12.82 1.28 5.53 0.55 8.33 0.83
VOC2 0.90 0.90 0.87 0.87 1.13 1.13 1.56 1.56 2.45 2.45CO9.55 9.55 6.37 6.37 2.33 2.33 3.10 3.10 4.88 4.88SO20.02 0.02 0.02 0.02 1.00E-02 1.00E-02 6.27E-03 6.27E-03 3.02E-03 3.02E-03
CO23 3,314 3,314 2,534 2,534 1,775 1,775 1775.36 1775.36 1775.36 1775.36CH430.13 0.13 0.10 0.10 0.07 0.07 0.07 0.07 0.07 0.07
N2O3 0.03 0.03 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.01
CO2e4 3,326 3,326 2,542 2,542 1,781 1,781 1781.46 1781.46 1781.46 1781.46
1. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.2. It is conservatively assumed that hydro-carbons (HC) are equivalent to the emission VOCs.
3. Emission factors from 40 CFR 98 Tables C-1 and C-2.73.96 CO23.00E-03 CH46.00E-04 N2O
4. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-35. Start up Parameters - Per Engine
Parameter Value Units100% load ramp up time 9.00 minutes75% load ramp up time 11.00 minutes50% load ramp up time 15.00 minutes25% load ramp up time 22.00 minutes
No load tests per year1 12 runs/yr
Annual no load test 1 runs/yrAnnual load bank tests per year1 1 runs/yrMonthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yrAnnual test - run time at 35% load (assumed ~25%)3 30 min/run
Annual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 147.30100% load time with SCR4 32.25 hr/yr 4,750.43100% load time without SCR 0.75 hr/yr 110.4850% load time without SCR 0.00 hr/yr 0.00
50% load time with SCR4 0.50 hr/yr 39.45
25% load time without SCR4 0.37 hr/yr 28.93
25% load time with SCR4 0.13 hr/yr 10.520% load time without SCR5 7.00 hr/yr 552.30
Total hours 42 hr/yr 5,639.40
5. Monthly testing at 0% load for 30 minutes.6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
Associated Fuel Use (gal/yr)
Max
Uncontrolled Emission Factors
Percent Load Power (kW)Fuel Usage(gal/hr)Fuel Usage(MMBtu/hr)Fuel Usage (gal/yr)Fuel Usage (MMBtu/yr)lb/hrPower(bhp)
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.
3. Annual load bank testing of 35% load for 30 min, then 55% load for 30 min, and then 85% load for 60 minutes.
2. No load testing is assumed to be at 10% load as emissions data is not available at 0% load.
4. All time not specified for testing is assumed to be run at 100% load.
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Table B-36. Criteria Pollutant and GHG Potential to Emit
(lb/hr)(tpy)(lb/hr)(tpy)PM 0.58 0.01 1.17 0.03NOx36.33 0.10 72.65 0.21VOC0.90 0.02 1.81 0.05CO9.55 0.18 19.09 0.36
SO2 0.02 3.56E-04 0.04 7.13E-04
CO2 3,314 63 6628.92 126.89CH40.13 2.57E-03 0.27 0.01N2O0.03 5.15E-04 0.05 1.03E-03CO2e3,326 64 6651.67 127.33
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)(lb/hr)(tpy)Benzene 7.76E-04 1.58E-02 3.31E-04 3.15E-02 6.63E-04Toluene2.81E-04 5.71E-03 1.20E-04 1.14E-02 2.40E-04Xylenes1.93E-04 3.92E-03 8.24E-05 7.85E-03 1.65E-04Formaldehyde7.89E-05 1.60E-03 3.37E-05 3.21E-03 6.74E-05Acetaldehyde2.52E-05 5.12E-04 1.08E-05 1.02E-03 2.15E-05Acrolein7.88E-06 1.60E-04 3.36E-06 3.20E-04 6.73E-06Naphthalene1.30E-04 2.64E-03 5.55E-05 5.29E-03 1.11E-041.58E-02 3.31E-04 3.15E-02 6.63E-043.03E-02 6.37E-04 6.07E-02 1.27E-03
Max HAPTotal HAP
Pollutant Potential to Emit per Engine Total Potential to Emit
Table B-37. Engine HAPs Emissions
Pollutant Total Potential Emissions for All EnginesPotential Emissions per Engine
1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
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Table B-38. Generator Information
Number of Engines Engine Manufacturer Engine Model Tier Generator Electrical
Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating
Hours per Unit1 Fuel Type Fuel Sulfer
Content (%)2
11 Kohler KD2500 Tier 4 Compliant 2,500 3,621 42 Diesel 0.0015%
1. Testing, maintenance, and repair hours:42 hrs/yr
2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.
Table B-39. Emissions Parameters CO NOX PM VOC
100%2,700 3,621 172 24 7,224 997 5.95 66.67 0.60 0.8375%2,025 2,716 151 21 6,342 875 15.63 23.66 0.89 0.5450%1,350 1,810 103 14 4,318 596 5.65 16.96 0.45 0.6325%675 905 59 8 2,465 340 11.01 8.78 0.60 0.51172247,224 997 15.63 66.67 0.89 0.83
Table B-40. Emissions ControlsPercent Load 100%75%50%25%10%
NOX Control Efficiency (%)1 90.0%90.0%90.0%90.0%0.0%
SCR warmup time (minutes)1 9.00 9.00 13.00 19.00 -1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-41. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr) Emissions 25% with SCR (lb/hr)
PM/PM10/PM2.51 0.60 0.60 0.89 0.89 0.45 0.45 0.60 0.60
NOX 66.67 6.67 23.66 2.37 16.96 1.70 8.78 0.88
VOC2 0.83 0.83 0.54 0.54 0.63 0.63 0.51 0.51
CO 5.95 5.95 15.63 15.63 5.65 5.65 11.01 11.01
SO23 4.39E-04 4.39E-04 3.30E-04 3.30E-04 2.20E-04 2.20E-04 1.10E-04 1.10E-04
CO24 3,870 3,870 3,398 3,398 2,313 2,313 1320.83 1320.83
CH44 0.16 0.16 0.14 0.14 0.09 0.09 0.05 0.05
N2O4 0.03 0.03 0.03 0.03 0.02 0.02 0.01 0.01
CO2e5 3,884 3,884 3,409 3,409 2,321 2,321 1325.37 1325.371. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.2. It is conservatively assumed that hydro-carbons (HC) are equivalent to the emission VOCs.
3. SO2 emissions using equation from AP-42 Table 3.4-1 footnote d: 8.09E-03*S1 =1.21E-07 (lb/hp-hr)4. Emission factors from 40 CFR 98 Tables C-1 and C-2.73.96 CO2 (kg/MMBtu)
3.00E-03 CH4 (kg/MMBtu)
6.00E-04 N2O (kg/MMBtu)
5. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1 CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-42. Start up Parameters - Per Engine
Parameter Value Units
100% load ramp up time 9.00 minutes75% load ramp up time 9.00 minutes50% load ramp up time 13.00 minutes25% load ramp up time 19.00 minutesNo load tests per year1 12 runs/yr
Annual no load test 1 runs/yr
Annual load bank tests per year1 1 runs/yr
Monthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yr
Annual test - run time at 35% load (assumed ~25%)3 30 min/run
Annual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 172.00100% load time with SCR4 32.25 hr/yr 5,547.00100% load time without SCR 0.75 hr/yr 129.0050% load time without SCR 0.00 hr/yr 0.0050% load time with SCR4 0.50 hr/yr 51.40
25% load time without SCR4 0.32 hr/yr 18.5925% load time with SCR4 0.18 hr/yr 10.760% load time without SCR5 7.00 hr/yr 410.90
Total hours 42 hr/yr 6,339.65
5. Monthly testing at 0% load for 30 minutes.
6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
Percent Load Power (kW)
2. No load testing is assumed to be at 10% load as emissions data is not available at 0% load.
4. All time not specified for testing is assumed to be run at 100% load.3. Annual load bank testing of 35% load for 30 min, then 55% load for 30 min, and then 85% load for 60 minutes.
Associated Fuel Use (gal/yr)
Uncontrolled Emission Factors
Fuel Usage (MMBtu/yr)lb/hrFuel Usage(MMBtu/hr)Fuel Usage (gal/yr)Fuel Usage(gal/hr)
Max
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.
Power(bhp)
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Table B-43. Criteria Pollutant and GHG Potential to Emit
(lb/hr)(tpy) (lb/hr)(tpy)PM 0.60 0.01 6.55 0.14
NOx 66.67 0.17 733.35 1.85VOC0.83 0.02 9.17 0.18
CO 5.95 0.14 65.48 1.58
SO2 4.39E-04 7.94E-06 0.00 0.00
CO2 3,870 71.33 42572.72 784.58CH40.16 0.00 1.73 0.03
N2O 0.03 0.00 0.35 0.01CO2e3,884 71.57 42718.81 787.27
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)(lb/hr)(tpy)Benzene 7.76E-04 1.84E-02 3.87E-04 2.03E-01 4.25E-03Toluene2.81E-04 6.67E-03 1.40E-04 7.34E-02 1.54E-03Xylenes1.93E-04 4.58E-03 9.62E-05 5.04E-02 1.06E-03Formaldehyde7.89E-05 1.87E-03 3.93E-05 2.06E-02 4.33E-04Acetaldehyde2.52E-05 5.98E-04 1.26E-05 6.58E-03 1.38E-04Acrolein7.88E-06 1.87E-04 3.93E-06 2.06E-03 4.32E-05
Naphthalene 1.30E-04 3.09E-03 6.48E-05 3.39E-02 7.13E-04
1.84E-02 3.87E-04 2.03E-01 4.25E-03
3.54E-02 7.44E-04 3.90E-01 8.18E-03
Max HAP
Pollutant Potential to Emit per Engine
Table B-44. Engine HAPs Emissions
Pollutant Potential Emissions per Engine Total Potential Emissions for All Engines
Total Potential to Emit
1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
Total HAP
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Table B-45. Generator Information
Number of Engines Engine Manufacturer Engine Model Tier Generator Electrical Capacity (kWe)
Engine Power Capacity (bhp)
Max Annual Operating
Hours per Unit1 Fuel Type Fuel Sulfer Content
(%)2
4 Cummins QSK60-G6 Tier 4 Compliant 2,000 2,922 42 Diesel 0.0015%1. Testing, maintenance, and repair hours:42 hrs/yr
2. From EPA, "Diesel Fuel Standards and Rulemakings", https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings.
Table B-46. Emissions Parameters
CO NOX PM VOC
100%2,179 2,922 141 19 5,935 819 1.56 34.14 0.26 0.7175%1,634 2,192 107 15 4,507 622 0.84 22.71 0.19 0.4850%1,090 1,461 82 11 3,444 475 1.56 9.99 0.45 0.4225%545 731 47 6 1,953 270 1.23 4.35 0.26 0.35141195,935 819 1.56 34.14 0.45 0.71
Table B-47. Emissions ControlsPercent Load 100%75%50%25%10%
NOX Control Efficiency (%)1 90.0%90.0%90.0%90.0%0.0%
SCR warmup time (minutes)1 8.00 10.00 15.00 20.00 -
1 Based on Information provided by SCR manufacturer (Miratech).Miratech
Table B-48. Criteria Pollutant and GHG Engine Emission Factors
Pollutant Emissions 100% without SCR (lb/hr)Emissions 100% with SCR (lb/hr)Emissions 75% without SCR (lb/hr)Emissions 75% with SCR (lb/hr)Emissions 50% without SCR (lb/hr)Emissions 50% with SCR (lb/hr)Emissions 25% without SCR (lb/hr)
Emissions 25% with SCR (lb/hr)PM/PM10/PM2.51 0.26 0.26 0.19 0.19 0.45 0.45 0.26 0.26
NOX 34.14 3.41 22.71 2.27 9.99 1.00 4.35 0.43
VOC2 2.06 2.06 0.48 0.48 0.42 0.42 0.35 0.35
CO 1.56 1.56 0.84 0.84 1.56 1.56 1.23 1.23
SO23 3.55E-04 3.55E-04 2.66E-04 2.66E-04 1.77E-04 1.77E-04 8.86E-05 8.86E-05
CO24 3,179 3,179 2414.40 2414.40 1845.12 1845.12 1046.32 1046.32
CH44 0.13 0.13 0.10 0.10 0.07 0.07 0.04 0.04
N2O4 0.03 0.03 0.02 0.02 0.01 0.01 0.01 0.01
CO2e5 3,190 3,190 2422.69 2422.69 1851.45 1851.45 1049.91 1049.91
1. It is conservatively assumed that emission factors for PM10 and PM2.5 are equivalent to the emission factor for PM.
2. VOC emission factor from AP-42 Table 3.4-1:7.05E-04 (lb/hp-hr)
3. SO2 emissions using equation from AP-42 Table 3.4-1 footnote d: 8.09E-03*S1 =1.21E-07 (lb/hp-hr)4. Emission factors from 40 CFR 98 Tables C-1 and C-2.
73.96 CO2 (kg/MMBtu)
3.00E-03 CH4 (kg/MMBtu)
6.00E-04 N2O (kg/MMBtu)
5. CO2e is the sum of GHG constituents multiplied by their respective global warming potential per 40 CFR 98 Table A-1.
1 CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-49. Start up Parameters - Per EngineParameter Value Units100% load ramp up time 8.00 minutes75% load ramp up time 10.00 minutes50% load ramp up time 15.00 minutes25% load ramp up time 20.00 minutes
No load tests per year1 12 runs/yr
Annual no load test 1 runs/yr
Annual load bank tests per year1 1 runs/yr
Monthly no load tests run time2 30 min/runAnnual no load test run time 60 min/runAdditional Startups6 5 runs/yrAnnual test - run time at 35% load (assumed ~25%)3 30 min/run
Annual test - run time at 55% load (assumed ~50%)3 30 min/runAnnual test - run time at 85% load (assumed ~100%)3 60 min/run
85% (~100%) load time with SCR4 1.00 hr/yr 141.30100% load time with SCR4 32.33 hr/yr 4,568.70100% load time without SCR 0.67 hr/yr 94.2050% load time without SCR 0.00 hr/yr 0.0050% load time with SCR4 0.50 hr/yr 41.0025% load time without SCR4 0.33 hr/yr 15.50
25% load time with SCR4 0.17 hr/yr 7.750% load time without SCR5 7.00 hr/yr 325.50Total hours 42 hr/yr 5,193.95
5. Monthly testing at 0% load for 30 minutes.
6. Scheduled startup time assumed to be at respective loads, all additional startup time assumed to be at 100% load to be conservative.
4. All time not specified for testing is assumed to be run at 100% load.
Max
Associated Fuel Use
(gal/yr)
Uncontrolled Emission Factors
Percent Load Power (kW)Power(bhp)Fuel Usage(gal/hr)Fuel Usage(MMBtu/hr)Fuel Usage (gal/yr)Fuel Usage (MMBtu/yr)lb/hr
1. It is assumed that there will be a startup for each test with corresponding ramp up for the SCR.
3. Annual load bank testing of 35% load for 30 min, then 55% load for 30 min, and then 85% load for 60 minutes.
2. No load testing is assumed to be at 10% load as emissions data is not available at 0% load.
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Table B-50. Criteria Pollutant and GHG Potential to Emit
(lb/hr)(tpy) (lb/hr)(tpy)PM 0.26 0.01 1.03 0.02
NOx 34.14 0.08 136.57 0.34VOC2.06 0.04 8.24 0.15
CO 1.56 0.03 6.22 0.13
SO2 3.55E-04 6.40E-06 1.42E-03 2.56E-05
CO2 3,179 58.44 12717.81 233.74CH40.13 2.37E-03 0.52 0.01
N2O 0.03 4.74E-04 0.10 1.90E-03CO2e3,190 58.64 12761.45 234.54
Emission Factor
(lb/MMBtu)1 (lb/hr)(tpy)(lb/hr)(tpy)Benzene 7.76E-04 1.51E-02 3.18E-04 6.05E-02 1.27E-03Toluene2.81E-04 5.48E-03 1.15E-04 2.19E-02 4.60E-04Xylenes1.93E-04 3.76E-03 7.90E-05 1.51E-02 3.16E-04Formaldehyde7.89E-05 1.54E-03 3.23E-05 6.15E-03 1.29E-04Acetaldehyde2.52E-05 4.91E-04 1.03E-05 1.97E-03 4.13E-05Acrolein7.88E-06 1.54E-04 3.23E-06 6.15E-04 1.29E-05
Naphthalene 1.30E-04 2.53E-03 5.32E-05 1.01E-02 2.13E-04
1.51E-02 3.18E-04 6.05E-02 1.27E-03
2.91E-02 6.11E-04 1.16E-01 2.44E-03Total HAPMax HAP
Pollutant Potential to Emit per Engine
Table B-51. Engine HAPs Emissions
Total Potential Emissions for All EnginesPotential Emissions per EnginePollutant
1. Emission factors from AP-42 Section 3.4, Tables 3.4-3 and 3.4-4
Total Potential to Emit
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Table B-52. Site Fuel Usage:
Per Engine Total Storage
(gal)
Throughput
(gal/yr)
MTU 15001 17 101.21 1,720.56 400 72,263.6
MTU 17501 2 111.95 223.90 400 9,404.00
MTU 20001 2 134.27 268.54 400 11,278.80
KD25001 11 150.94 1,660.38 400 69,736.15
Cummins 20001 4 123.67 494.66 3,650 20,775.80
Office Gen 1 90 90.00 500 3,780.00
187,238.35
Table B-53. Site Parameters
Parameter Run time (hr/yr)
100% load time1 34.00
50% load time2 0.50
25% load time 0.50
0% load time 7.00
Total hours 42.00
1. Inclusive of 85% load time, which is assumed to be ~100% load.
2. Inclusive of 55% load time, assumed to be ~50% load.
Table B-54. Bulk Storage Tanks and Associated Engines
Bulk Tanks Quantity of Each
Engine Type Engine Type
Bulk Tank #1 4 MTU 1500
Bulk Tank #2 4 MTU 1500
1 MTU 1500
2 MTU 1750
1 MTU 2000
Bulk Tank #4 4 MTU 1500
Bulk Tank #5 2 KD 2500
Bulk Tank #6 2 KD 2500
Bulk Tank #7 2 KD 2500
Bulk Tank #8 2 KD 2500
Bulk Tank #9 2 KD 2500
1 KD 2500
1 MTU 2000
Bulk Tank #11 4 MTU 1500
Primary Tank
Bulk Tank #3
Bulk Tank #10
1. Fuel usage at 0% load assumed to be equivalent to closest load with manufactuer data avaible.
Engine Number of Engines
Fuel Usage (gal/hr)
Site Total (gal/yr)
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Table B-55. Primary Tank Throughputs
Engine Tanks Throughput (gal/yr)1,2.3
MTU 1500 Primary tanks 72,264
MTU 1750 Primary tanks 9,404
MTU 2000 Primary tanks 11,279
KD 2500 Primary tanks 69,736
Cummins 20000 Primary tanks 20,776
Office Gen Primary tanks 3,780
Total 187,238
1. Annual operating time (hr/yr)42
2. Number of Tanks:
MTU 1500 Primary tanks 17
MTU 1750 Primary tanks 2
MTU 2000 Primary tanks 2
KD 2500 Primary tanks 11
Cummins 20000 Primary tanks 4
Office Gen Primary tanks 1
Table B-56. Bulk Storage Tank Throughputs
Engine Tanks Throughput (gal/yr)1,2,3
Bulk Tank #1 19,837
Bulk Tank #2 19,837
Bulk Tank #3 22,510
Bulk Tank #4 19,837
Bulk Tank #5 14,793
Bulk Tank #6 14,793
Bulk Tank #7 14,793
Bulk Tank #8 14,793
Bulk Tank #9 14,793
Bulk Tank #10 13,976
Bulk Tank #11 19,837
Total 189,796
2. Annual operating time (hr/yr)49
1. The throughput of each bulk tank is determined by summing the throughputs of the engines
associated with it.
Novva SLC Common, LLC.Trinity Consultants 18 of 22
Reduction in Emissions
Table B-57. Tank VOC Potential to Emit
Loading loss emission factor (lb/103 gal)2 0.03
Loading loss all belly tanks (lb/yr)3,4 20.32
Loading loss all belly tanks (tpy)0.01
Average hourly total loading loss all belly tanks
(lb/hr)5 2.32E-03
Where,
LL, loading loss (lb/[103 gal of liquid loaded]) =0.03
S, saturation factora =1.45
P, true vapor pressure of diesel (psia)b =6.00E-03
M, molecular weight of vapors of diesel (lb/lb-mol)b = 130.00
T, Temperature (R)b =522.97
eff, overall reduction efficiency =0.00
b) AP 42 Table 7.1-2
c) AP 42 Table 7.1-7 (F)63.3
3. Conversion factors:
1000 gal/Mgal
4. Safety Factor 2
5. Annual operating time (hr/yr):8760
Table B-58. Tank Annual HAP Potential to Emit
(lb/yr)(tpy)
Benzene 1.64%3.80E-05 1.60E-03 1.67E-04
Ethylbenzene 2.3%5.27E-05 2.21E-03 2.31E-04
Hexane 0.3%7.89E-06 3.31E-04 3.45E-05
Naphthalene 0.3%6.73E-06 2.83E-04 2.95E-05
Toluene 18.2%4.22E-04 0.02 1.85E-03
Xylenes 44.0%1.02E-03 0.04 4.47E-03
0.04 4.47E-03
0.06 6.77E-03
1. Determined from TankESP HAPs speciation.
Max HAPs
Total HAPs
Total Annual Emissions All
Diesel Tanks
VOC Emissions1
1. Includes (1) vapors formed in the empty tank by evaporation of residual product from previous
loads, (2) vapors transferred to the tank in vapor balance systems as product is being unloaded,
and (3) vapors generated in the tank as the new product is being loaded.
2. AP 42 Section 5.2 Transportation and Marketing of Petroleum Liquids
a) AP 42 Table 5.2-1, for splash loading and dedicated normal service.
Average
Total Hourly
Emissions
All Diesel
Vapor HAP Composition
(wt %)1Pollutant
Novva SLC Common, LLC.Trinity Consultants 19 of 22
Reduction in Emissions
Table B-59. Boiler Emission Parameters
Parameter Value Unit
Boiler 1 Capacity 2 MMBtu/hr
Equivalent Gas Hours:8,760 hr/yr
Natural Gas Heating Value (HHV):1 1,020 MMBtu/MMscf
Table B-60. Boiler - Criteria & GHG Potential to Emit
(lb/hr)(tpy)
NOX 100 lb/MMscf 0.196 0.86
CO 84 lb/MMscf 0.165 0.72
PM10 7.6 lb/MMscf 0.015 0.07
PM2.5 7.6 lb/MMscf 0.015 0.07
SO2 0.6 lb/MMscf 1.18E-03 5.15E-03
VOC 5.5 lb/MMscf 0.0108 0.05
Lead 0.0005 lb/MMscf 9.80E-07 4.29E-06
CO2 116.98 lb/MMBtu 233.95 1024.72
N2O 2.2E-04 lb/MMBtu 4.41E-04 1.93E-03
CH4 2.20E-03 lb/MMBtu 4.41E-03 1.93E-02
CO2e 117.10 lb/MMBtu 234.20 1025.78
CO2 1
N2O 298
CH4 25
1. HHV obtained from AP-42, footnote a of Table 1.4-1
Pollutant Emission Factor 1,2 Total Emissions
1. Natural gas emission factors determined by AP-42 Section 1.4.
2. Emission factor for greenhouse gases calculated from 40 CFR Part 98, Subpart C, Tables C-1 and C-2,
using the Global Warming Potentials provided in Subpart A, Table A-1:
Novva SLC Common, LLC.Trinity Consultants 20 of 22
Reduction in Emissions
Table B-61. Boiler - HAPs Potential to Emit
(lb/hr)(tpy)
2-Methylnaphthalene 2.40E-05 lb/MMscf 4.71E-08 2.06E-07
3-Methylchloranthrene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
7,12-Dimethylbenz(a)anthracene 1.60E-05 lb/MMscf 3.14E-08 1.37E-07
Acenaphthene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Acenaphthylene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Anthracene 2.40E-06 lb/MMscf 4.71E-09 2.06E-08
Benz(a)anthracene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Benzene 2.10E-03 lb/MMscf 4.12E-06 1.80E-05
Benzo(a)pyrene 1.20E-06 lb/MMscf 2.35E-09 1.03E-08
Benzo(b)fluoranthene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Benzo(g,h,i)perylene 1.20E-06 lb/MMscf 2.35E-09 1.03E-08
Benzo(k)fluoranthene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Chrysene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Dibenzo(a,h)anthracene 1.20E-06 lb/MMscf 2.35E-09 1.03E-08
Dichlorobenzene 1.20E-03 lb/MMscf 2.35E-06 1.03E-05
Fluoranthene 3.00E-06 lb/MMscf 5.88E-09 2.58E-08
Fluorene 2.80E-06 lb/MMscf 5.49E-09 2.40E-08
Formaldehyde 7.50E-02 lb/MMscf 1.47E-04 6.44E-04
Hexane 1.80E+00 lb/MMscf 3.53E-03 1.55E-02
Indeno(1,2,3-cd)pyrene 1.80E-06 lb/MMscf 3.53E-09 1.55E-08
Naphthalene 6.10E-04 lb/MMscf 1.20E-06 5.24E-06
Phenanathrene 1.70E-05 lb/MMscf 3.33E-08 1.46E-07
Pyrene 5.00E-06 lb/MMscf 9.80E-09 4.29E-08
Toluene 3.40E-03 lb/MMscf 6.67E-06 2.92E-05
Arsenic Compounds 2.00E-04 lb/MMscf 3.92E-07 1.72E-06
Beryllium Compounds 1.20E-05 lb/MMscf 2.35E-08 1.03E-07
Cadmium Compounds 1.10E-03 lb/MMscf 2.16E-06 9.45E-06
Chromium Compounds 1.40E-03 lb/MMscf 2.75E-06 1.20E-05
Cobalt Compounds 8.40E-05 lb/MMscf 1.65E-07 7.21E-07
Lead Compounds 5.00E-04 lb/MMscf 9.80E-07 4.29E-06
Manganese Compounds 3.80E-04 lb/MMscf 7.45E-07 3.26E-06
Mercury Compounds 2.60E-04 lb/MMscf 5.10E-07 2.23E-06
Nickel Compounds 2.10E-03 lb/MMscf 4.12E-06 1.80E-05
Selenium Compounds 2.40E-05 lb/MMscf 4.71E-08 2.06E-07
Max HAP 3.53E-03 0.02
Total HAPs 3.70E-03 0.00
Variable Emission Factor1 Total Emissions
1. Natural gas emission factors from AP-42, Tables 1.4-3 and 1.4-4.
Novva SLC Common, LLC.Trinity Consultants 21 of 22
Reduction in Emissions
Table 62. MTU 12V4000G74S DS1500
CO NOX/NO2 PM VOC SO2 CO NOX/NO2 PM VOC SO2
100%1,736 2,328 111.00 15.32 1.10 8.70 0.07 0.32 4.00E-03 1,910 15,103 121.52 555.52 6.94
75%1,302 1,746 85.30 11.77 1.10 7.10 0.12 0.44 4.00E-03 1,432 9,244 156.24 572.88 5.2150%868 1,164 59.60 8.22 1.10 5.70 0.10 0.79 5.00E-03 954.80 4,948 86.80 685.72 4.34
25%434 582 59.60 8.22 2.80 4.70 0.35 2.24 7.00E-03 1,215 2,040 151.90 972.16 3.04111.00 15.32 2.80 8.70 0.35 2.24 7.00E-03 1,910 15,103 156.24 972.16 6.94
1. Per manufacturer specifications.
2. Diesel HHV 0.138 MMBtu/gal
3. Not to exceed values used when available
Table 63. MTU 16V4000 DS2000
CO NOX/NO2 PM VOC SO2 CO NOX/NO2 PM VOC SO2
100%2,279 3,056 147.30 20.33 1.90 7.23 0.116 0.18 4.00E-03 4,330 16,477 264.36 410.22 9.1275%1,709 2,292 112.60 15.54 1.69 6.48 0.188 0.23 4.00E-03 2,888 11,074 321.29 393.07 6.84
50%1,138 1,526 78.90 10.89 0.93 5.11 0.094 0.45 4.00E-03 1,058 5,815 106.97 512.10 4.55
25%569 763 78.90 10.89 2.47 4.41 0.320 1.24 5.00E-03 1,405 2,509 182.08 705.56 2.85
10%228 306 78.90 10.89 9.71 16.57 1.665 4.88 6.00E-03 2,214 3,778 379.62 1,113 1.37
147.30 20.33 9.71 16.57 1.67 4.88 6.00E-03 4,330 16,477 379.62 1,113 9.12
1. Per manufacturer specifications.
2. Diesel HHV 0.138 MMBtu/gal
3. Not to exceed values used when available
Table 64. MTU 12V4000 DS1750
CO NOX/NO2 PM VOC SO2 CO NOX/NO2 PM VOC SO2
100%1,910 2,561 123.00 16.97 1.31 8.03 0.072 0.14 4.00E-03 2,502 15,337 137.52 267.40 7.6475%1,432 1,920 93.00 12.83 1.19 6.93 0.107 0.26 4.00E-03 1,704 9,924 153.22 372.32 5.73
50%955 1,281 65.00 8.97 1.49 5.78 0.185 0.43 4.00E-03 1,423 5,520 176.68 410.65 3.8225%477 640 65.00 8.97 2.21 5.39 0.179 1.30 5.00E-03 1,054 2,571 85.38 620.10 2.39
10%191 256 65.00 8.97 7.31 15.63 1.834 5.38 7.00E-03 1,396 2,985 350.29 1,028 1.34
123.00 16.97 7.31 15.63 1.83 5.38 7.00E-03 2,502 15,337 350.29 1,028 7.64
1. Per manufacturer specifications.
2. Diesel HHV 0.138 MMBtu/gal
3. Not to exceed values used when available
Table 65. Kohler KD62V12 KD2500
CO NOX/NO2 PM VOC SO2 CO NOX/NO2 PM VOC SO2
100%2,700 3,621 172.00 23.74 1.00 11.20 0.10 0.14 -2,700 30,240 270.00 378.00 -
75%2,025 2,716 151.00 20.84 3.50 5.30 0.20 0.12 -7,088 10,733 405.00 243.00 -
50%1,350 1,810 102.80 14.19 1.90 5.70 0.15 0.21 -2,565 7,695 202.50 283.50 -
25%675 905 58.70 8.10 7.40 5.90 0.40 0.34 -4,995 3,983 270.00 229.50 -
172.00 23.74 7.40 11.20 0.40 0.34 -7,088 30,240 405.00 378.00 -
1. Per manufacturer specifications.
2. Diesel HHV 0.138 MMBtu/gal
3. Not to exceed values used when available
Table 66. Cummins QSK60-G6
CO NOX/NO2 PM VOC SO2 CO NOX/NO2 PM VOC SO2
100%2,179 2,922 141.30 19.50 0.24 7.11 0.05 0.15 0.15 705.35 15,487 116.88 321.43 321.4375%1,634 2,192 107.30 14.81 0.17 6.30 0.05 0.13 0.15 382.06 10,300 87.66 219.16 241.07
50%1,090 1,461 82.00 11.32 0.48 4.16 0.19 0.17 0.17 705.35 4,529 204.55 189.94 189.94
25%545 731 46.50 6.42 0.76 3.62 0.21 0.30 0.19 558.40 1,972 116.88 160.71 102.27
141.30 19.50 0.76 7.11 0.21 0.30 0.19 705.35 15,487 204.55 321.43 321.43
1. Per manufacturer specifications.
2. Diesel HHV 0.138 MMBtu/gal
3. Not to exceed values used when available
MAX
MAX
Uncontrolled Emission Factors3
Fuel Usage1
(gal/hr)
Fuel Usage2
(MMBtu/hr)Percent Load Power 1
(kW)
Power
(bhp)1
Uncontrolled Emission Factors
Percent Load Power 1
(kW)
Power
(bhp)1 Fuel Usage1
(gal/hr)Fuel Usage2
(MMBtu/hr)g/hp-hr g/hr
MAX
Uncontrolled Emission Factors3 Uncontrolled Emission Factors
Percent Load Power 1
(kW)Power(bhp)1 Fuel Usage1
(gal/hr)Fuel Usage2
(MMBtu/hr)g/kW-hr
MAX
Percent Load Power 1
(kW)
Power
(bhp)1 Fuel Usage1
(gal/hr)
MAX
Percent Load Power 1
(kW)Power(bhp)1 Fuel Usage1
(gal/hr)
Uncontrolled Emission Factors3 Uncontrolled Emission Factors
g/kW-hr g/hr
Fuel Usage2
(MMBtu/hr)
Uncontrolled Emission Factors3 Uncontrolled Emission Factors
g/hrg/kW-hr
g/hr
Uncontrolled Emission Factors3
g/kW-hr g/hr
Uncontrolled Emission Factors
Fuel Usage2
(MMBtu/hr)
Novva SLC Common, LLC.Trinity Consultants 22 of 22
NOVVA SLC COMMON, LLC. MODELING REPORT
NO2 1-hour and Annual NAAQS / Modeling Report
Novva SLC Common, LLC. / West Jordan Data Center

Prepared By:
TRINITY CONSULTANTS
4525 Wasatch Boulevard, Suite 200
Salt Lake City, UT 84124
[phone]

For:
Novva SLC Common, LLC.
6477 Wells Park Road
West Jordan, Utah 84081

May 2024

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants i
TABLE OF CONTENTS
1. INTRODUCTION 1-1
1.1 General Information ................................................................................................. 1-1
1.2 Project Scope ............................................................................................................ 1-1
1.3 Plant Layout .............................................................................................................. 1-1
2. AIR DISPERSION MODELING DESCRIPTION 2-1
2.1 Model Selection ......................................................................................................... 2-1
2.2 Meteorological Data .................................................................................................. 2-1
2.3 Terrain Elevations ..................................................................................................... 2-1
2.4 Receptors .................................................................................................................. 2-1
2.5 UTM Coordinate System ............................................................................................ 2-5
2.6 Building Downwash .................................................................................................. 2-5
3. NO2 SOURCE PARAMETERS AND EMISSION RATES 3-1 3.1 NO2 Point Source Parameters and Emission Rates .................................................... 3-1
3.1.1 Combustion Equipment Modeling Parameters and Emission Rates ................................ 3-1
3.1.2 Combustion Equipment Operating Parameters ........................................................... 3-1 3.2 Nearby NO2 Sources - Emission Rates ....................................................................... 3-2
4. NO2 MODELING ANALYSIS 4-1
4.1 NO2 Special Processing ............................................................................................. 4-1
4.2 Background NO2 Concentrations ............................................................................... 4-1
4.3 Background Ozone Concentrations ........................................................................... 4-2
4.4 Modeled NO2 Concentration ...................................................................................... 4-2
4.5 NO2 NAAQS Analysis Results ..................................................................................... 4-3
4.6 NO2 Mitsubishi Method Analysis Results ................................................................... 4-5
APPENDIX A. WEST JORDAN FACILITY MODELING PARAMETERS AND EMISSION RATES A-1

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 1-1
1. INTRODUCTION
1.1 General Information
Novva’s West Jordan facility (Facility) is a data center facility located at 6477 Wells Park Rd, West Jordan,
UT 84081. Novva is proposing an administrative amendment to DAQE-AN160660001-22 for a reduction in
emissions. In the time since this AO was issued, supply chain issues have required Novva to search for
alternative emergency generators with accompanying diesel storage tanks to meet the datacenters back up
power supply requirements. Of the 40 originally permitted 2,328 HP emergency generator engines, only
seventeen (17) were obtained; however, Novva found nineteen (19) suitable alternatives. Consequently,
Novva is proposing to install a total of 37 emergency engines, as opposed to the 41 generators that were
included in the submitted NOI. Additionally, after a comprehensive evaluation of the optimal operational
parameters for testing and maintenance procedures, Novva has found that they will not require a full 100
hours per year of operation. Instead, Novva proposes to take a limit on their operation and use an
enforceable limit on sitewide fuel usage. Novva is submitting a reduction in emissions amendment letter in
conjunction with this modeling report. As described in the amendment letter the following thirty-seven (37)
diesel-fired emergency generator engines have been obtained for the Facility:

► One (1) CAT C15 762 horsepower (hp) diesel-fired emergency generator engine;
► Four (4) Cummins 2,922 hp diesel-fired emergency generator engines;
► Seventeen (17) MTU 2,328 hp diesel-fired emergency generator engines;
► Two (2) MTU 2,561 hp diesel-fired emergency generator engines;
► Two (2) MTU 3,056 hp diesel-fired emergency generator engines; and
► Eleven (11) Kohler 3,621 hp diesel-fired emergency generator engines.

This report outlines the methodology that Novva has used in conducting air dispersion modeling. It
describes the results that demonstrate compliance with the NAAQS for one (1)-hour and annual nitrogen
dioxide (NO2) at the Facility. Dispersion modeling has been conducted in accordance with R307-410-3 and
40 Code of Federal Regulations (CFR) Part 51, Appendix W Guideline on Air Quality Models.
1.2 Project Scope
Thirty-seven (37) diesel-fired emergency generator engines were installed at the Facility. Each diesel-fired
generator engine will be equipped with a selective catalytic reduction (SCR) unit.

Equipment included in the 1-hour and annual NO2 modeling analysis of the West Jordan Facility are as
follows:

► One (1) Natural Gas-Fired Boiler.
► Thirty-seven (37) Diesel-Fired Emergency Generator Engines.
1.3 Plant Layout
The general facility layout is shown in Figure 1-1, below. The one (1) 762 hp diesel-fired generator engine
will supply emergency power to office and thirty-six (36) diesel-fired emergency generator engines will
provide emergency power to the data hall. The natural gas-fired boiler provides comfort heating to the
office building.

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Figure 1-1. West Jordan Facility Site Plan

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2. AIR DISPERSION MODELING DESCRIPTION
This section describes the air quality dispersion modeling analysis performed to estimate the ambient air
impacts of Novva’s operation of the Facility. All modeling results were compared to both the NO2 NAAQS for
the 1-hour and annual averaging period. The objective of the NAAQS analysis is to demonstrate through air
quality dispersion modeling that emissions from the Facility do not cause or contribute to an exceedance of
the 1-hour/annual NO2 NAAQS. Four (4) nearby offsite area sources were included at the direction of UDAQ.
Dispersion Modeling was conducted in accordance with R307-410-3 and 40 CFR Part 51, Appendix W
Guideline on Air Quality Models.
2.1 Model Selection
Near-field dispersion modeling was performed using the latest version of the AERMOD modeling system,
version 23132, which is an EPA approved, steady-state Gaussian mathematical plume model. AERMOD is
composed of three (3) modular components: AERMAP, the terrain preprocessor that characterizes the
terrain and generates source and receptor elevations and surrounding hill height scales; AERMET, the
meteorological preprocessor that processes raw surface and upper air meteorological observations for use
by AERMOD; and AERMOD, the control module and modeling processor.
2.2 Meteorological Data
Meteorological data used in the dispersion modeling analysis was processed and provided by UDAQ.1 Data
consists of five (5) individual years (2017 through 2021) of National Weather Service (NWS) surface data
collected at the Salt Lake City Airport that were then concatenated into a five (5)-year file. Concurrent upper
air observations used in AERMET were obtained from the Salt Lake City Airport.
2.3 Terrain Elevations
Terrain elevations for the Facility’s sources, receptors and buildings were determined using National
Elevation Dataset (NED), the primary elevation data product of the United States Geologic Survey (USGS).2
NED data are distributed in geographic coordinates in units of decimal degrees, and in conformance with the
North American Datum of 1983 (NAD 83). The NED used for this analysis is at a resolution of 1/3 arc-
second (about 10 meter) grid spacing. Elevations were converted from the NED grid spacing to the air
dispersion model receptor spacing using the AERMOD preprocessor, AERMAP version 18081. All data
obtained from the NED files was checked for completeness and spot-checked for accuracy.
2.4 Receptors
A modeling domain was developed for the near-field analyses to encompass the location of the maximum
modeled concentration from Novva’s sources. Discrete receptor locations in AERMOD were based on UTM
coordinates in the NAD83 datum, Zone 12N. An initial modeling grid extending at least 10.0 kilometers from
the Facility center was established. The receptor grid was developed to ensure that maximum pollutant
concentrations were captured by the model. The Facility boundary is based on the existing Facility
boundary.
The model receptors consisted of boundary receptors and gridded receptors with the following spacing:

1 Email from Dave Prey, UDAQ, March 08, 2024. 2 NED data obtained at https://viewer.nationalmap.gov/basic/#/ downloaded August 14, 2023.

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 2-2
► The ambient air boundary was placed at the Facility property line and consists of discrete receptors
placed at 25-meter intervals.
► The fine grid contains 50-meter spaced receptors extending to at least 950 meters from the center of
the Facility.
► The medium grid contains 100-meter spaced receptors extending to at least 2,200 meters from the
center of the Facility.
► The coarse grid contains 1,000-meter spaced receptors extending to 11 kilometers from the center of
the Facility.
► Additional receptors were placed on the neighborhood and road north of the facility at 25-meter
intervals.

Figure 2-1 and Figure 2-2 below show the ambient air boundary receptors (shown in purple below) and
gridded off-site receptors (yellow). Figure 2-2 does not show the full extent of the coarse-grid receptors, but
shows their spacing.

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Figure 2-1. Boundary Receptors

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Figure 2-2. Fine, Medium, and Coarse Grid and Boundary Receptors

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 2-5
2.5 UTM Coordinate System
In all modeling analyses, input and output data files, the locations of emission sources, structures, and
receptors were represented in the Universal Transverse Mercator (UTM) coordinate system are based on
NAD83. In this grid, the world is divided into 60 north-south zones, each covering a strip 6° wide in
longitude. The general area of the site is located in UTM Zone 12N. In each UTM zone, coordinates are
measured north and east in meters. The northing values are measured continuously from zero at the
equator, in a northerly direction. A central meridian through the middle of each 6° zone is assigned an
easting value of 500,000 meters. Grid values to the east of this central meridian, as in the case of the site,
are greater than 500,000 meters.
2.6 Building Downwash
Emission sources were evaluated in terms of their proximity to nearby structures. The following structures
were included for the Building Profile Input Program (BPIP), which predicts the effects of building
downwash:

► One (1) data center building (Building 1); and
► One (1) office building.

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3. NO2 SOURCE PARAMETERS AND EMISSION RATES
3.1 NO2 Point Source Parameters and Emission Rates
All diesel-fired emergency generator engines and the boiler were modeled as point sources. The generator
engines are all uncapped point sources and the boiler is a capped point source. Each generator engine is
equipped with a selective catalytic reduction (SCR) unit for controlling NO2 emissions. All point sources
require release height, stack temperature, stack velocity, and stack diameter. This section explains the
methodology to obtain the modelling parameters required for point sources. All inputs for stack source
parameters can be seen in Appendix A of this modeling analysis.
3.1.1 Combustion Equipment Modeling Parameters and Emission Rates
The modeled point sources of NO2 at the Facility consist of the equipment and their release parameters as
seen in Table 3-1. Stack information was taken from manufacturers’ and/or design specifications.
Table 3-1. Release Parameters for NO2 Point Sources
Unit Engine
Make
Stack
Height
(m)
Stack
Temp.
(K)
Stack
Velocity
(m/s)
Stack
Diameter
(m)
Diesel-Fired Emergency
Generator Engines
Cummins 12.80 751.48 42.37 0.46
MTU 1500 12.80 708.15 34.30 0.46
MTU 1750 12.80 738.15 36.70 0.46
MTU 2000 12.80 753.15 45.73 0.46
CAT 2.78 804.15 52.47 0.20
Kohler 12.80 773.15 58.07 0.46
Boiler - 2.44 435.93 7.45 0.15
3.1.2 Combustion Equipment Operating Parameters
Outside of emergency situations, the diesel-fired emergency generator engines will only operate for testing
and maintenance purposes. Novva has evaluated various operating scenarios in which operating and
maintenance may be conducted on the diesel-fired generators. Novva has determined groupings of diesel-
fired generator engines to be operated concurrently for testing and maintenance purposes. Table 3-2
outlines these groups. For modeling purposes, the boiler will operate 24 hours per day, 7 days a week, 52
weeks a year in each operating scenario. The operating scenarios are reflected in the corresponding
modeling files submitted with this report.

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Table 3-2. Diesel-Fired Emergency Engine Operating Groups
Operating Scenario Source Group Source 1 Source 2
7 AM – 7 PM NOFF OFFICE -
7 AM – 7 PM NS1G1 GENN01 GENN02
7 AM – 7 PM NS1G2 GENN03 GENN04
7 AM – 7 PM NS2G1 GENN05 GENN06
7 AM – 7 PM NS2G2 GENN07 GENN08
7 AM – 7 PM NS3G1 GENN09 GENN10
7 AM – 7 PM NS3G2 GENN11 GENN12
7 AM – 7 PM NS4G1 GENN13 GENN14
7 AM – 7 PM NS4G2 GENN15 GENN16
7 AM – 7 PM NS5G1 GENN17 GENN18
7 AM – 7 PM NS5G2 GENN19 GENN20
7 AM – 7 PM NS6G1 GENN21 GENN22
7 AM – 7 PM NS6G2 GENN23 GENN24
7 AM – 7 PM NS7G1 GENN25 GENN26
7 AM – 7 PM NS7G2 GENN27 GENN28
7 AM – 7 PM NS8G1 GENN29 GENN30
7 AM – 7 PM NS8G2 GENN31 GENN32
7 AM – 7 PM NS10G1 GENN33 GENN34
7 AM – 7 PM NS10G2 GENN35 GENN36
3.2 Nearby NO2 Sources - Emission Rates
Nearby NO2 sources included in models of the Nephi Facility consist of the following, as received from
UDAQ:3
Nearby Point Source IDs
► SLC1_G02
► SLC1_G03
► SLC1_G04
► SLC1_G05
► SLC2_G14
► HEATEXCH
► BOILER4
► SLC3_G30
► SLC3_G32
► STCK1
► STCK2
► STCK3
► STCK4
► STCK5
► STCK6
► STCK7
► STCK8
► STCK9
► STCK10
► STCK11
► STCK12
► STCK1NL
► STCK2NL
► STCK3NL
► STCK4NL
► STCK5NL
► STCK6NL
► STCK7NL
► STCK8NL
► STCK9NL
► STCK10NL
► STCK11NL
► STCK12NL
► GEN
► PLASMA96
► PLASMA60
► FICEP
► ROBOT
► PLASMA20
► OA_FPUMP
Nearby Volume Source IDs
► WELDING

3 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-1
4. NO2 MODELING ANALYSIS
The NO2 modeling analysis predicts ambient concentrations of NO2 as a result of emissions from the Facility
in conjunction with nearby source emissions and background concentrations. The modeling output includes
tabulated modeling results as compared to the NO2 1-hour and Annual NAAQS.
4.1 NO2 Special Processing
The majority of the emissions of NOX from air emission sources are in the form of nitric oxide (NO), whereas
EPA has established a NAAQS for NO2. EPA’s “Guideline on Air Quality Models” describes a three-tiered
screening approach to calculating NO2 concentrations based on dispersion model predictions of NOX
concentrations.

The three tiers, arranged in order from simplest to most refined, are:

• Tier 1 – Assume full conversion of NO to NO2, so that the NOX predicted by AERMOD is 100% NO2.
• Tier 2 – Ambient Ratio Method (ARM), where model predicted NOX concentrations are multiplied by a
NO2/NOX ambient ratio, derived from ambient monitoring data.
• Tier 3 – More detailed methods that account for the plume dispersion and chemistry may be considered
on a case-by-case basis, including the Ozone Limiting Method (OLM) and the Plume Volume Molar Ratio
Method (PVMRM).

For the NAAQS modeling of the Facility, a Tier 3 methodology utilizing OLM was used for the assessment of
NO2 impacts.
4.2 Background NO2 Concentrations
Background concentrations for NO2 for this modeling analysis were given by UDAQ from their Herriman
Monitoring station.4 The background data consists of design values calculated from data monitored from
2019-2021. The value used in the modeling analysis is the three-year average, high-third-high (H3H) of
seasonal 1-hour NO2 background. The background concentrations for NO2 are presented in Table 4-1 below.

4 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-2
Table 4-1. UDAQ-Provided NO2 Background Concentrations, H3H Seasonal 1-hour
Hour 3 Year Average (ppb)
Winter Spring Summer Fall
1.00 26.467 13.233 9.500 12.467
2.00 24.133 12.833 10.300 11.500
3.00 23.400 12.633 10.133 11.933
4.00 21.300 12.233 9.300 10.667
5.00 21.867 10.600 8.333 10.100
6.00 23.367 14.300 10.267 13.567
7.00 24.767 17.467 11.400 17.433
8.00 28.267 18.100 10.833 19.600
9.00 25.967 15.667 8.900 16.467
10.00 22.200 12.333 6.967 12.500
11.00 20.167 8.867 5.967 9.967
12.00 20.000 8.800 5.367 9.233
13.00 20.333 7.400 4.433 8.033
14.00 19.433 6.467 3.733 7.533
15.00 20.333 7.133 3.567 8.500
16.00 21.800 7.000 3.700 11.267
17.00 24.767 6.633 3.267 13.267
18.00 33.567 7.500 3.900 15.833
19.00 33.100 7.633 4.800 16.567
20.00 32.367 9.000 7.500 13.433
21.00 30.567 9.833 7.267 13.967
22.00 28.267 11.633 8.567 14.633
23.00 27.333 11.600 12.900 17.067
24.00 27.000 12.167 11.533 13.233
4.3 Background Ozone Concentrations
Background concentrations for ozone for this modeling analysis were given by UDAQ from their Herriman
Monitoring station.5 The background data consists of hourly ozone data that is concurrent with the
meteorological data provided by UDAQ. The background concentrations for ozone will be included in the
form of an ozone background file, along with the modeling files delivered with this report.
4.4 Modeled NO2 Concentration
The resulting concentrations of 1-hour and annual NO2 from this air dispersion modeling analysis were
compared against the NO2 1-hour and annual NAAQS to demonstrate that emissions from the Facility do not
cause or contribute to an exceedance of the 1-hour and annual NO2 NAAQS. The primary NAAQS is the
maximum concentration ceiling, measured in terms of total concentration of a pollutant in the atmosphere,
which is defined as the “level of air quality which the U.S. EPA judges are necessary, with an adequate
margin of safety, to protect the public health.”6 The 1-hour NO2 NAAQS requires the 8th highest
concentration over the five (5) modeled years to be compared to the standard. The annual NO2 NAAQS
requires that the 1st highest high concentration over the five (5) modeled years be compared to the

5 Email from Dave Prey, UDAQ, March 08, 2024. 6 40 CFR 50.2(b).

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-3
standard. The modeled concentration was added to the background concentrations for comparison to the
NAAQS. This calculation was completed within the AERMOD modeling system.
4.5 NO2 NAAQS Analysis Results
A NAAQS analysis considers the impact from the sources at the Facility, nearby sources, and background
concentrations to yield a total concentration which is then compared to the NAAQS. For 1-hour NO2, that
value is 188 µg/m3; for annual NO2, that value is 100 µg/m3. Table 4-2 presents the model-predicted
concentrations from the Facility, nearby sources, and background concentrations according to the operating
scenarios given in Section 3.1.2, as well as comparisons to the 1-hour and annual NO2 NAAQS.

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-4
Table 4-2. NO2 NAAQS Compliance Demonstration
Diesel-Fired
Emergency Generator Engines Operating Scenario1
Source Group2 Pollutant Averaging Period
Model-Predicted Concentration Including
Background (µg/m3)3
NAAQS (µg/m3)
Percent of NAAQS
(%)
7 AM – 7 PM NOFF
NO2
1-hour 142.7 188 75.9
Annual 32.0 100 32.0
7 AM – 7 PM NS1G1 1-hour 133.3 188 70.9
Annual 32.0 100 32.0
7 AM – 7 PM NS1G2 1-hour 133.7 188 71.1
Annual 32.0 100 32.0
7 AM – 7 PM NS2G1 1-hour 139.9 188 74.4
Annual 32.0 100 32.0
7 AM – 7 PM NS2G2 1-hour 142.2 188 75.6
Annual 32.0 100 32.0
7 AM – 7 PM NS3G1 1-hour 144.1 188 76.6
Annual 32.0 100 32.0
7 AM – 7 PM NS3G2 1-hour 144.9 188 77.1
Annual 32.0 100 32.0
7 AM – 7 PM NS4G1 1-hour 149.8 188 79.7
Annual 32.0 100 32.0
7 AM – 7 PM NS4G2 1-hour 149.8 188 79.7
Annual 32.0 100 32.0
7 AM – 7 PM NS5G1 1-hour 147.2 188 78.3
Annual 32.0 100 32.0
7 AM – 7 PM NS5G2 1-hour 147.0 188 78.2
Annual 32.0 100 32.0
7 AM – 7 PM NS6G1 1-hour 161.5 188 85.9
Annual 33.4 100 33.4
7 AM – 7 PM NS6G2 1-hour 161.2 188 85.8
Annual 33.5 100 33.5
7 AM – 7 PM NS7G1 1-hour 161.3 188 85.8
Annual 33.5 100 33.5
7 AM – 7 PM NS7G2 1-hour 159.8 188 85.0
Annual 33.8 100 33.8
7 AM – 7 PM NS8G1 1-hour 158.3 188 84.2
Annual 33.7 100 33.7
7 AM – 7 PM NS8G2 1-hour 153.2 188 81.5
Annual 32.8 100 32.8
7 AM – 7 PM NS10G1 1-hour 147.4 188 78.4
Annual 32.0 100 32.0
7 AM – 7 PM NS10G2 1-hour 144.8 188 77.0
Annual 32.0 100 32.0
1. The boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario. 2. Each source group is incorporated within the corresponding air dispersion model files submitted with this report.
3. The 1-hour averaging period H8H is compared to the NAAQS. The annual averaging period H1H is compared to the NAAQS.

Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-5
In addition to this report, Novva is providing the AERMOD Input and Output files for UDAQ’s review. These
will be submitted separately.
4.6 NO2 Mitsubishi Method Analysis Results
For the 1-hour NO2 modeling, the “Mitsubishi Method” was employed to demonstrate compliance at on-
property receptors for the following nearby facilities, located to the east and south of the Facility:7

► PLBNEBAY;
► ORACLE;
► SME; and
► DANONE.
Specifically, for one nearby facility at a time, Novva’s data center and the other nearby facilities were
modeled to obtain total concentrations at receptor locations located on the property of the nearby facility in
question. For these models, the sources from the facility in question were turned off within the model (i.e.,
for this subset of receptors, a separate model was executed with all regional sources excluding the nearby
facility in question’s sources). This process was completed for each modeling scenario and source group
listed in Section 3.1.2 of this report. The maximum modeled concentrations excluding each nearby facility’s
on-site receptors are provided in Table 4-2. The maximum modeled concentrations including each nearby
facility’s on-site receptors are provided in Table 4-3 for reference.

7 U.S. EPA Memorandum from Robert D. Bauman (Chief SO2/Particulate Matter Programs Branch) to Gerald Fontenot (Chief Air Programs Branch, Region VI), Ambient Air, October 17, 1989.
Novva SLC Common, LLC. | NO2 Modeling Analyses Trinity Consultants 4-6
Table 4-3. Mitsubishi Method NO2 NAAQS Compliance Demonstration
Nearby Source
Diesel-Fired Emergency Generator Engines Operating Scenario1
Source Group2 Pollutant Averaging Period
Max Model-Predicted
Concentration Including Background (µg/m3)3
NAAQS (µg/m3) Percent of NAAQS
Danone 7 AM – 7 PM NS6G1
NO2
1-hour 161.5 188 85.9%
7 AM – 7 PM NS7G2 Annual 33.7 100 33.7%
SME 7 AM – 7 PM NS6G1 1-hour 161.5 188 85.9%
7 AM – 7 PM NS7G2 Annual 33.7 100 33.7%
Oracle 7 AM – 7 PM NS6G1 1-hour 161.4 188 85.9%
7 AM – 7 PM NS7G2 Annual 33.7 100 33.7%
eBay 7 AM – 7 PM NS6G1 1-hour 161.5 188 85.9%
7 AM – 7 PM NS7G2 Annual 33.7 100 33.7%
1.The boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario.2.Each source group is incorporated within the corresponding air dispersion model files submitted with this report.
3.Both the 1-hour averaging period H8H and the annual averaging period H1H are compared to the NAAQs.

Novva SLC Common, LLC. | NO2 Modeling Analysis Trinity Consultants A-1
APPENDIX A. WEST JORDAN FACILITY MODELING PARAMETERS AND EMISSION RATES
Table A-1. NO2 Uncapped Point Source Input Parameters
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN01 C2000 411449.0 4492171.4 1533.36 1.113449 12.80 751.48 42.37 0.46
GENN02 C2000 411448.9 4492167.4 1533.44 1.113449 12.80 751.48 42.37 0.46
GENN03 C2000 411448.8 4492164.0 1533.51 1.113449 12.80 751.48 42.37 0.46
GENN04 C2000 411448.6 4492160.5 1533.59 1.113449 12.80 751.48 42.37 0.46
GENN05 MTU1500
Miratech 411461.2 4492136.7 1533.82 0.922973 12.80 708.15 34.30 0.46
GENN06 MTU1500
Miratech 411460.8 4492127.9 1533.94 0.922973 12.80 708.15 34.30 0.46
GENN07 MTU1500 Miratech 411461.0 4492123.9 1533.98 0.922973 12.80 708.15 34.30 0.46
GENN08 MTU1500
Miratech 411460.8 4492119.2 1534.04 0.922973 12.80 708.15 34.30 0.46
GENN09 MTU1500
Miratech 411460.8 4492115.8 1534.07 0.922973 12.80 708.15 34.30 0.46
GENN10 MTU1500
Miratech 411460.6 4492106.7 1534.15 0.922973 12.80 708.15 34.30 0.46
GENN11 MTU1500
Miratech 411460.6 4492102.8 1534.17 0.922973 12.80 708.15 34.30 0.46
GENN12 MTU1500
Miratech 411460.5 4492093.5 1534.24 0.922973 12.80 708.15 34.30 0.46
GENN13 MTU1500 SafetyPower 411460.1 4492081.4 1534.31 1.048833 12.80 708.15 34.30 0.46
GENN14 MTU1750 411460.1 4492072.5 1534.35 1.065090 12.80 738.15 36.70 0.46
GENN15 MTU1750 411460.0 4492068.2 1534.36 1.065090 12.80 738.15 36.70 0.46
GENN16 MTU2000 411459.8 4492059.5 1534.37 1.075593 12.80 753.15 45.73 0.46
GENN17 MTU1500 Miratech 411460.0 4492050.1 1534.34 0.922973 12.80 708.15 34.30 0.46
GENN18 MTU1500
Miratech 411459.9 4492043.8 1534.40 0.922973 12.80 708.15 34.30 0.46

Novva SLC Common, LLC. | NO2 Modeling Analysis Trinity Consultants A-2
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN19 MTU1500
Miratech 411459.7 4492037.5 1534.49 0.922973 12.80 708.15 34.30 0.46
GENN20 MTU1500
Miratech 411459.6 4492030.4 1534.64 0.922973 12.80 708.15 34.30 0.46
GENN21 K2500 411459.5 4492020.2 1534.79 1.974000 12.80 773.15 58.07 0.46
GENN22 K2500 411459.4 4492014.3 1534.87 1.974000 12.80 773.15 58.07 0.46
GENN23 K2500 411459.4 4492009.3 1534.92 1.974000 12.80 773.15 58.07 0.46
GENN24 K2500 411459.3 4492004.6 1534.97 1.974000 12.80 773.15 58.07 0.46
GENN25 K2500 411459.2 4492000.0 1535.01 1.974000 12.80 773.15 58.07 0.46
GENN26 K2500 411459.0 4491989.3 1534.97 1.974000 12.80 773.15 58.07 0.46
GENN27 K2500 411458.7 4491976.7 1534.87 1.974000 12.80 773.15 58.07 0.46
GENN28 K2500 411458.7 4491969.3 1534.83 1.974000 12.80 773.15 58.07 0.46
GENN29 K2500 411458.6 4491962.5 1534.85 1.974000 12.80 773.15 58.07 0.46
GENN30 K2500 411458.5 4491955.4 1534.92 1.974000 12.80 773.15 58.07 0.46
GENN31 K2500 411458.3 4491948.2 1535.02 1.974000 12.80 773.15 58.07 0.46
GENN32 MTU2000 411458.0 4491931.1 1535.46 1.075593 12.80 753.15 45.73 0.46
GENN33 MTU1500
Miratech 411457.8 4491915.0 1535.78 0.922973 12.80 708.15 34.30 0.46
GENN34 MTU1500 Miratech 411457.6 4491905.8 1535.75 0.922973 12.80 708.15 34.30 0.46
GENN35 MTU1500
Miratech 411457.4 4491894.1 1535.72 0.922973 12.80 708.15 34.30 0.46
GENN36 MTU1500
Miratech 411457.2 4491884.1 1535.75 0.922973 12.80 708.15 34.30 0.46
OFFICE Office 411546.4 4492186.4 1530.74 0.581444 2.78 804.15 52.47 0.20
Table A-2. NO2 Capped Point Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevation (m) Emission Rate (g/s)
Stack Height
(m)
Stack Temp.
(K)
Stack Velocity
(m/s)
Stack Diameter
(m)
BOIL1 Boiler 411519.2 4492181.3 1531.66 0.024705 2.44 435.93 7.45 0.15

Novva SLC Common, LLC. | NO2 Modeling Analysis Trinity Consultants A-3
Table A-3. NO2 Nearby Uncapped Point Source Input Parameters
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
SLC1_G02 eBay 411283.5 4490966.2 1546.50 1.826368 5.71 668.13 16.56 0.71
SLC1_G03 eBay 411295.4 4490966.2 1546.75 1.826368 5.71 668.13 16.56 0.71
SLC1_G04 eBay 411307.8 4490966.2 1546.99 1.826368 5.71 668.13 16.56 0.71
SLC1_G05 eBay 411319.4 4490966.2 1547.25 1.826368 5.71 668.13 16.56 0.71
SLC2_G14 eBay 411383.5 4490828.0 1545.61 6.853707 6.71 735.43 33.70 0.61
HEATEXCH Danone 412215.9 4492747.5 1506.58 0.774887 13.59 394.26 5.02 1.52
BOILER4 Danone 412212.9 4492725.0 1506.79 0.042839 14.33 478.15 11.71 0.81
SLC3_G30 eBay 411130.4 4490957.3 1550.73 1.216438 8.23 614.18 19.14 0.46
SLC3_G32 eBay 411130.8 4490944.0 1550.75 0.662975 3.84 706.19 7.42 0.46
STCK1 Oracle 412204.1 4491301.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK2 Oracle 412204.4 4491308.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK3 Oracle 412204.8 4491314.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK4 Oracle 412205.8 4491320.9 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK5 Oracle 412207.4 4491334.0 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK6 Oracle 412208.2 4491340.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK7 Oracle 412208.5 4491346.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK8 Oracle 412209.6 4491353.2 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK9 Oracle 412201.5 4491257.3 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK10 Oracle 412200.4 4491250.9 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK11 Oracle 412195.5 4491241.0 1516.69 0.851785 5.14 713.71 107.48 0.36
STCK12 Oracle 412206.1 4491205.0 1516.69 0.220709 4.08 708.71 90.92 0.20
STCK1NL Oracle 412204.1 4491301.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK2NL Oracle 412204.4 4491308.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK3NL Oracle 412204.8 4491314.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK4NL Oracle 412205.8 4491320.9 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK5NL Oracle 412207.4 4491334.0 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK6NL Oracle 412208.2 4491340.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK7NL Oracle 412208.5 4491346.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK8NL Oracle 412209.6 4491353.2 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK9NL Oracle 412201.5 4491257.3 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK10NL Oracle 412200.4 4491250.9 1516.69 0.846706 6.50 729.26 96.10 0.36

Novva SLC Common, LLC. | NO2 Modeling Analysis Trinity Consultants A-4
STCK11NL Oracle 412195.5 4491241.0 1516.69 0.851785 5.14 713.71 107.48 0.36
STCK12NL Oracle 412206.1 4491205.0 1516.69 0.220709 4.08 708.71 90.92 0.20
GEN SME 412943.3 4492242.3 1497.23 1.348177 3.66 773.15 12.94 0.18
PLASMA96 SME 412698.0 4492190.0 1505.37 0.109996 3.25 294.26 2.93 1.14
PLASMA60 SME 412698.0 4492180.0 1505.38 0.109996 3.72 294.26 4.41 1.14
FICEP SME 412585.0 4491991.0 1504.60 0.109996 3.25 294.26 2.93 1.14
ROBOT SME 412657.0 4492214.0 1505.17 0.109996 2.55 294.26 4.60 1.14
PLASMA20 SME 412679.0 4492107.0 1505.45 0.000000 3.37 294.26 3.67 1.14
OA_FPUMP Oracle 412202.8 4491280.7 1516.69 0.120743 3.05 764.00 45.44 0.06
Table A-4 NO2 Nearby Volume Source Input Parameters
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Release
Height (m)
Init. lat.
dim. (m)
Init. vert.
dim. (m)
WELDING 412651.0 4492163.0 1505.43 0.000000 5.00 23.25 4.65
Table A-5. Polygon Buildings.
ID Description X Coordinate (m) Y Coordinate (m) Elevation (m) Height (ft)
BLDG1 Building1 411538.3 4491829.9 1534.77 41.0
OFFICE2 - 411499.0 4492230.4 1531.89 47.7
BLDG2 Building 2 411358.0 4492205.8 1535.74 41.0
BLDG3 Building 3 411670.5 4491811.0 1531.78 41.0
OFFICE1 - 411496.2 4492173.1 1532.34 41.0

NOTICE OF INTENT AIR PERMIT APPLICATION
Novva Data Centers > West Jordan, Utah

Novva SLC Common, LLC / Utah Data Center

Prepared By: Trinity Consultants
4525 Wasatch Boulevard, Suite 200 Salt Lake City, UT 84124
[phone]

Prepared For: Novva SLC Common, LLC.
6477 West Wells Park Road West Jordan, UT 84081

May 30, 2024

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants i
TABLE OF CONTENTS
1. EXECUTIVE SUMMARY 1-1
2. GENERAL INFORMATION 2-1 2.1 Description of Facility ............................................................................................... 2-1 2.2 Source Size Determination ........................................................................................ 2-1 2.3 Fees .......................................................................................................................... 2-1
2.4 Forms ........................................................................................................................ 2-1
3. DESCRIPTION OF PROJECT AND PROCESS 3-1
3.1 Description of Project and Process ............................................................................ 3-1
3.2 Site plan .................................................................................................................... 3-1
4. EMISSIONS RELATED INFORMATION 4-1
4.1 Internal Combustion – Natural Gas Reciprocating Internal Combustion Engines (RICE)
4-1
5. BEST AVAILABLE CONTROL TECHNOLOGIES 5-1 5.1 BACT Methodology .................................................................................................... 5-1
5.1.1 Step 1 – Identify All Reasonably Available Control Technologies................................... 5-1
5.1.2 Step 2 – Eliminate Technically Infeasible Options ....................................................... 5-1
5.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness ...................... 5-2
5.1.4 Step 4 – Evaluate Most Effective Controls and Document Results ................................. 5-2
5.1.5 Step 5 – Select BACT ............................................................................................... 5-2 5.2 Potential for the Consideration of Alternative Equipment ......................................... 5-2 5.3 Natural Gas Reciprocating Engine Generators BACT ................................................. 5-3
5.3.1 Natural Gas Reciprocating Engines NOX Technologies ................................................. 5-3 Step 1 – Identify All Reasonably Available Control Technologies ...................................... 5-3 Step 2 – Eliminate Technically Infeasible Options ............................................................. 5-5 Steps 3 - Step 5 – Select BACT ........................................................................................... 5-6
5.3.2 Natural Gas Engines CO Technologies ....................................................................... 5-6 Step 1 – Identify All Reasonably Available Control Technologies ...................................... 5-6 Step 2 – Eliminate Technically Infeasible Options ............................................................. 5-7 Steps 3 - Step 5 – Select BACT ........................................................................................... 5-8
5.3.3 Natural Gas Reciprocating Engines VOC Technologies ................................................. 5-8 Step 1 – Identify All Reasonably Available Control Technologies ...................................... 5-8 Step 2 – Eliminate Technically Infeasible Options ........................................................... 5-10 Steps 3 - Step 5 – Select BACT ......................................................................................... 5-10
5.3.4 Natural Gas Reciprocating Engines PM Technologies ................................................. 5-10 Step 1 – Identify All Reasonably Available Control Technologies .................................... 5-10 Step 2 – Eliminate Technically Infeasible Options ........................................................... 5-11 Steps 3 - Step 5 – Select BACT ......................................................................................... 5-12
5.3.5 Natural Gas Reciprocating Engines SO2 Technologies ................................................ 5-12 Step 1 – Identify All Reasonably Available Control Technologies .................................... 5-12 Step 2 – Eliminate Technically Infeasible Options ........................................................... 5-13 Steps 3 - Step 5 – Select BACT ......................................................................................... 5-13
5.3.6 Natural Gas Reciprocating Engines Ammonia Considerations ..................................... 5-13
6. EMISSION IMPACT ANALYSIS 6-1
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants ii
6.1 Comparison to Modeling Thresholds ......................................................................... 6-1
6.2 Source Size Determination ........................................................................................ 6-1
7. OFFSET REQUIREMENTS 7-1
8. APPLICABLE REGULATIONS 8-1 8.1 Utah Air Quality Regulations ..................................................................................... 8-1
8.1.1 UAC R307-107 General Requirements: Breakdowns .................................................... 8-4
8.1.2 UAC R307-165: Emission Testing .............................................................................. 8-5
8.1.3 UAC R307-201: Emission Standards: General Emission Standards ................................ 8-5
8.1.4 UAC R307-325: Ozone Nonattainment and Maintenance Areas: General Requirements .. 8-5 8.2 Federal Regulations .................................................................................................. 8-6
8.2.1 NSPS Subpart A (General Provisions) ........................................................................ 8-6
8.2.2 NSPS Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines) ......................................................................................................... 8-6
Emission Limitation ....................................................................................................................8-6
Compliance Requirements ..........................................................................................................8-7
Recordkeeping ...........................................................................................................................8-7
8.2.3 NESHAP Subpart A (General Provisions) .................................................................... 8-8
8.2.4 NESHAP SUBPART ZZZZ (NESHAP for Stationary Reciprocating Internal Combustion
Engines) ........................................................................................................................... 8-8
Emissions & Operating Limitations ..............................................................................................8-8
Testing and Compliance Demonstration .......................................................................................8-8
Notification Requirements ...........................................................................................................8-9
APPENDIX A. FORMS A-1
APPENDIX B. EMISSION CALCULATIONS B-2
APPENDIX C. AIR DISPERSION MODELING REPORT C-1
APPENDIX D. EMISSION CALCULATION SUPPORTING DOCUMENTS D-1

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 1-1
1. EXECUTIVE SUMMARY
Novva SLC Common, LLC (Novva) is proposing an expansion of its West Jordan data center. This facility is
located within an area of Salt Lake County which is currently designated as a serious nonattainment area
(NAA) of the 2006 24-hour National Ambient Air Quality Standards (NAAQS) for particulate matter (PM) with
an aerodynamic diameter of 2.5 microns or less (PM2.5), a moderate NAA of sulfur dioxide (SO2), a moderate
NAA of the 2015 8-hour NAAQS for ozone, and an attainment area of all other criteria pollutants.1
This Notice of Intent (NOI) air permit application has been developed for Novva to request a modification to
their approval order (AO) DAQE-AN160660001-22 for their West Jordan Data Center. Novva proposes to
install 72 new natural gas reciprocating internal combustion engines (RICE) which will power generators
intended to provide primary power for the site’s two (2) proposed new data center buildings. Each engine
will be equipped with several high efficiency control technologies which are further detailed later in this
application in the Best Available Control Technology (BACT) analysis. The proposed engines’ purpose will be
to provide the facility with primary electrical power.

This NOI air permit application is being submitted in accordance with the Utah Division of Air Quality’s
(UDAQ’s) rules, Utah Administrative Code (UAC) R307-401 and includes all supporting documentation to
obtain authorization for the installations described above. The proposed operations constitute a minor
modification at a minor source. Air dispersion modeling has been conducted for nitrogen dioxides (NO2), carbon monoxide (CO), and particulate matter with an aerodynamic diameter of 10 microns or less (PM10) to
demonstrate that the operations will not cause or contribute to an exceedance of their perspective NAAQS
averaging periods. Appendix B Table B-1 summarizes the emissions resulting from the Novva operations.

1 Per U.S. EPA Green Book, available at https://www3.epa.gov/airquality/greenbook/anayo_ut.html, accessed May 2024.
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2. GENERAL INFORMATION
2.1 Description of Facility
► Company Name: Novva SLC Common, LLC.
► Company Contact: Steven Boyce – VP Infrastructure Research and Design
► Contact Number: [phone]
► Contact Email: [e-mail]
► Company Contact: Anthony Gustin Mission Critical Project Manager
► Contact Number: [phone]
► Contact Email: [e-mail]
► Mailing Address: 12382 Gateway Park Place, B300 Draper, UT 84020
► Facility Address 6524 West Old Bingham HWY, West Jordan, UT 84081
► County: Salt Lake County
► UTM Coordinates (“NAD 83”): 411,485 m Easting, 4,491,982 m Northing, UTM Zone 12
► Primary SIC Code: 7376 (Computer Facilities Management Services)
► Area Designation: Nonattainment area of PM2.5, SO2, and O3
► Source Size Determination: Minor Stationary Source
► Current AO: DAQE-AN160660001-22

2.2 Source Size Determination

As presented in Appendix B, Table B-1, site-wide emissions at the Facility are less than the major source
thresholds (MST) for all criteria pollutants. However, the project will qualify as a major source for hazardous
air pollutants (HAPs) under the National Emission Standards for Hazardous Air Pollutants (NESHAP).
2.3 Fees
Novva will use UDAQ’s Payment Portal to pay the invoice for the following UDAQ NOI fees associated with
this submittal:

► “Application Filing Fee” for the “Modification at a Minor Source” source type = $500
► “Application Review Fee” for the “Modification at a Minor Source” source type in a non-attainment area =
$2,300
► Total UDAQ fees = $2,800

Novva understands that the total permit review fee is based on the total actual time spent by UDAQ staff
processing this NOI. Upon issuance of the approval order (AO), if the total review time is more than 20
standard hours, UDAQ will invoice Novva at $115 per hour for the additional time above 20 standard hours.
2.4 Forms
The following UDAQ forms have been included Appendix A of this application:

► Form 1: Notice of Intent Application Checklist
► Form 2: Company Information
► Form 4: Project Information
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► Form 5: Emissions Information
► Form 11: Internal Combustion Engines

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3. DESCRIPTION OF PROJECT AND PROCESS
3.1 Description of Project and Process
The operation of a data center requires a reliable power source to power its data halls. Typically, data
centers rely on grid power as a primary source of power. However, local utilities are not able to provide
sufficient power for the Facility’s planned operations in sufficient time to satisfy Novva’s business needs. To
meet their business needs, Novva is proposing to install 72 natural gas RICE to power 3.3 megawatt (MW)
generators to provide primary power for the two (2) proposed new buildings. Each engine will be equipped
with several high efficiency control technologies. The engines will operate on natural gas supplied from an
external provider. Of the 72 proposed RICE, a rotation of four (4) units will always be down for
maintenance. Given the transient nature of data center power requirements, depending on the electrical
load required by the data hall, Novva’s system of RICE will typically have multiple additional units on
‘standby mode’ (i.e. not operational) as they will represent availability for load response and redundancy for
Novva’s customer. The PTE calculated in this application is representative of a full PTE for each of the 72
units, operating twenty-four (24) hours a day, seven (7) days a week, and 365 days a year to represent a
conservative emissions total.

The data center’s electrical load demand will be inherently transient, requiring a quick response to large
fluctuations. This unique load scenario is the primary reason why turbines have not been selected for this
project, and thus have not been evaluated in the BACT analysis. Additionally, to achieve the levels of
redundancy required for the data center, the installation of multiple additional turbines and/or several diesel
fired emergency generator engines would have been necessary. As such, RICE have been selected as the
best solution for Novva’s business needs, as well as the best way to minimize emissions. Novva’s
commitment to advancing cleaner solutions for their data center operations is evident in the controls
proposed.

The combustion of natural gas in the engines, in combination with the control technologies proposed, has
the potential to emit the following air pollutants:

► Particulate matter with an aerodynamic diameter less than 10 microns (PM10);
► Particulate matter with an aerodynamic diameter less than 2.5 microns (PM2.5);
► Nitrogen Oxides (NOX);
► Volatile organic compounds (VOC);
► Carbon Monoxide (CO);
► Sulfur Dioxide (SO2);
► Greenhouse Gases (GHGs);
► Hazardous air pollutants (HAPs); and
► Ammonia (NH3).

Detailed emission calculations are included in Appendix B of the NOI. Air dispersion modeling has been
completed, demonstrating that the proposed project will not cause or contribute to an exceedance of the
NO2, CO, and PM10 NAAQS. The modeling report and results have been included in Appendix C of this NOI
air permit application.
3.2 Site plan
The property boundaries of the West Jordan data center are shown in Figures 3-1 and 3-2, in red.
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 3-2
Figure 3-1. West Jordan Facility General Location

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Figure 3-2. West Jordan Facility Property Boundary

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4. EMISSIONS RELATED INFORMATION
This section details the methodology used to calculate controlled and uncontrolled emissions for criteria
pollutants (i.e., PM2.5, PM10, NOX, CO, SO2), GHGs, VOCs, and HAPs associated with each emission unit and
any associated fugitive emissions as regulated by R307-401-5(2)(b). Detailed emission calculation tables are
included in Appendix B of this application. Supporting documentation is included in Appendix D.
4.1 Internal Combustion – Natural Gas Reciprocating Internal Combustion Engines (RICE)

The facility will have seventy-two (72) natural gas RICE with a maximum power output of 4,387.57 brake
horsepower (bhp) per engine. Emission calculations were performed for all natural gas prime power engines
with a proposed 8,760 hours of annual operation. Calculations for the criteria pollutants are based on the
annual hours of operation at the maximum power output of each engine, which has been derated to be
representative of the site’s elevation in accordance with manufacturer specifications and the following
equation (see Appendix D):
Fuel Load Output =100%−(0.85% for every 328 ft above 3280 ft)

The uncontrolled NOX, CO, VOC, PM, SO2 and NH3 emission factors (EF) were obtained from manufacturer
specifications. Emission factors for PM10 and PM2.5 are conservatively assumed to be equivalent to the
emission factors for PM. The maximum hourly emissions rate per engine of PM10, PM2.5, and SO2 are
calculated in the following equation:
E =EFiP�0.0022 lbg�
where:
E = component i emission rate, pound per hour (lb/hr)
EFi = emission factor for component i, grams per brake horsepower-hour (g/bhp-hr)
P = engine power, bhp

The annual uncontrolled PTE of PM10, PM2.5, and SO2 is calculated by multiplying the hourly emission rate by
the number of RICE (i.e., 72 RICE) and the annual hours of operations (i.e., 8,760 hours per year (hr/yr)).

HAPs emissions from natural gas combustion are calculated using the methodology in AP-42, Section 3.2.
Individual HAP emissions from n
atural gas combustion are calculated using the equation listed below:
Ei =EFiNHPt �1 ton2000 lb�
where:
Ei = component i emission rate, tons per year (tpy)
EFi = emission factor for component i, pound per million British Thermal Units (lb/MMBtu)
N = number of engines, dimensionless
H = brake-specific fuel consumption, MMBtu/bhp-hr
P = engine power, bhp
t = annual hours of operation per engine, hr/yr

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 4-2

EFs for HAPs are obtained from AP-42, Section 3.2, Table 3.2-2. Total HAP emissions are calculated by
summing the individual HAPs as calculated in the former equation.

All 4,387.6 bhp RICE are equipped with aftermarket selective catalytic reduction (SCR) and catalytic oxidizer
emission control systems to control NOX, CO, and VOC (including volatile organic HAPs) emissions. It is
assumed that each RICE always operates with all control devices in place. Accordingly, emissions of NOX,
CO, VOC, and certain HAPs associated with the controlled engines are calculated using the following
equations:

Maximum controlled hourly emission Elb/hr = PNEFi(1 −CEi)�0.0022 lbg�
where:
Elb/hr = component i controlled emission rate, lb/hr
P = engine power, bhp
N = number of engines operating at any one time, dimensionless
EFi = uncontrolled emission factor, g/bhp-hr
CEi = control efficiency, %

Annual controlled emissions Etpy = PNtotEFi(1 −CEi)t �0.0022 lbg��ton2000 lb�
where:
Etpy = component i emission rate, tpy
P = engine power, bhp
Ntot = total number of engines, dimensionless
EFi = uncontrolled emission factor, g/bhp-hr
CEi = control efficiency, %
t = annual hours of operation per engine, hr/yr

Ammonia emission calculations were performed for all RICE with SCR emission control systems. Ammonia
emissions are anticipated to occur from ammonia slip, which is the result of unreacted ammonia becoming
entrained in the exhaust gas. Ammonia slip occurs only during periods of SCR operation. Calculations for
ammonia exiting the engine exhaust stack have been provided by the vendors and manufacturers of the
SCR systems.

Emissions for ammonia are calculated using the following equation:
ENH3 =EFNH3P �0.0022 lbg�
where:
ENH3 = ammonia emission rate, lb/hr
EFNH3 = emission factor for ammonia, g/bhp-hr
P = engine power, bhp

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 4-3
GHG emissions from natural gas combustion are calculated using the methodology contained in the EPA
GHG MRR located at 40 CFR Part 98. Individual GHG emissions from natural gas combustion are calculated using the equation listed below:
Ei =EFiNHPt�1 ton907 kg�
where:
Ei = component i emission rate, tpy
EFi = emission factor for component i, kg/MMBtu
N = number of engines, dimensionless
H = brake-specific fuel consumption, MMBtu/bhp-hr
P = engine power, bhp
t = annual hours of operation, hr/yr

The calculated emissions of individual GHGs are then converted to CO2e by multiplying by the corresponding
global warming potential (GWP) for each GHG.
𝐶𝐶𝑂𝑂2𝑒𝑒=�𝐸𝐸𝑖𝑖𝐺𝐺𝑖𝑖

where:
CO2e = CO2 equivalent emissions, tpy
Ei = component i emission rate, tpy
Gi = GWP, dimensionless
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-1
5. BEST AVAILABLE CONTROL TECHNOLOGIES
5.1 BACT Methodology
EPA has defined BACT as follows:
… means an emissions limitation (including a visible emissions standard) based on
the maximum degree of reduction for each regulated NSR pollutant which would be
emitted from any proposed major stationary source or major modification which the
reviewing authority, on a case-by-case basis, taking into account energy,
environmental, and economic impacts and other costs, determines is achievable for
such source or modification through application of production processes or available
methods, systems, and techniques, including fuel cleaning or treatment or innovative
fuel combustion techniques for control of such pollutant… 2
In a memorandum dated December 1, 1987, the EPA detailed its preference for a “top-down” analysis which
contains five (5) steps.3 If it can be shown that the most stringent level of control is technically,
environmentally, or economically infeasible for the unit in question, then the next most stringent level of
control is determined and similarly evaluated. This process continues until the BACT level under
consideration cannot be eliminated by any substantial or unique technical, environmental, or economic
objections. Presented below are the five basic steps of a “top-down” BACT review as identified by the EPA.
5.1.1 Step 1 – Identify All Reasonably Available Control Technologies
Available control technologies are identified for each emission unit in question. The following methods are
used to identify potential technologies: 1) researching the RACT/BACT/LAER Clearinghouse (RBLC)
database, 2) surveying regulatory agencies, 3) drawing from previous engineering experience, 4) surveying
air pollution control equipment vendors, and/or 5) surveying available literature. Additionally, current CTG’s
as well as UAC R307, and proposed rules were reviewed to establish a current presumptive norm specific to
the 8-hour Ozone NWF NAA.
5.1.2 Step 2 – Eliminate Technically Infeasible Options
To ensure the presumptive norm established applies to the emission source in question a full review of
available control technologies is conducted in the second step of the BACT analysis. In this step each
technology is reviewed for technical feasibility and those that are clearly technically infeasible are
eliminated. EPA states the following with regard to technical feasibility:4
A demonstration of technical infeasibility should be clearly documented and should
show, based on physical, chemical, and engineering principles, that technical
difficulties would preclude the successful use of the control option on the emissions
unit under review.

2 40 CFR 51.165(a)(1)(xl) 3 U.S. EPA, Office of Air and Radiation. Memorandum from J.C. Potter to the Regional Administrators. Washington, D.C. December 1, 1987. 4 U.S. EPA, New Source Review Workshop Manual (Draft): Prevention of Significant Deterioration and Nonattainment Area Permitting, October 1990.
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5.1.3 Step 3 – Rank Remaining Control Technologies by Control Effectiveness
Once technically infeasible options are removed from consideration, the remaining options are ranked based
on their control effectiveness. If there is only one remaining option or if all the remaining technologies could
achieve equivalent control efficiencies, ranking based on control efficiency is not required.
5.1.4 Step 4 – Evaluate Most Effective Controls and Document Results
Beginning with the most effective control option in the ranking, detailed economic, energy, and
environmental impact evaluations are performed. If a control option is determined to be economically
feasible without adverse energy or environmental impacts, it is not necessary to evaluate the remaining
options with lower control effectiveness.

The economic evaluation centers on the cost effectiveness of the control option. Costs of installing and
operating control technologies are estimated and annualized following the methodologies outlined in the
EPA’s OAQPS Control Cost Manual (CCM) and other industry resources.5 Note that the purpose of this
analysis is not to determine whether controls are affordable for a particular company or industry, but
whether the expenditure effectively allows the source to meet pre-established presumptive norms.
5.1.5 Step 5 – Select BACT
In the final step the lowest emission limitation is proposed as BACT along with any necessary control
technologies or measures needed to achieve the cited emission limit. This proposal is made based on the
evaluations from the previous steps.
5.2 Potential for the Consideration of Alternative Equipment
Throughout the power industry turbines are commonly utilized to produce electricity. Novva originally
considered turbines as an alternative to natural gas-powered reciprocating engines; however, the use of
turbines was eliminated from further consideration for the following reasons:

► Natural gas reciprocating engines offer further flexibility for the redundancy necessary in the datacenter
industry; and
► The lead time for a natural gas engine was significantly shorter than that of a turbine.

In a letter to E3 Consulting LLC on December 13, 2005, EPA addressed the consideration of alternative
processes in a BACT analysis. This letter contains the following language:
EPA’s view is that, through [the definition of BACT], Congress distinguished
“production processes and available methods, systems and techniques” that are
potentially applicable to a particular type of facility and should be considered in the
analysis of BACT from “alternative” to the proposed source that would wholly replace
the proposed facility with a different type of facility.
In accordance with this definition, Novva is not further considering the use of turbines as an alternative to
natural gas reciprocating engines for its proposed prime power application.

5 Office of Air Quality Planning and Standards (OAQPS), EPA Air Pollution Control Cost Manual, Sixth Edition, EPA 452-02-001 (https://www.epa.gov/economic-and-cost-analysis-air-pollution-regulations/cost-reports-and-guidance-air-pollution), Daniel C. Mussatti & William M. Vatavuk, January 2002.
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5.3 Natural Gas Reciprocating Engine Generators BACT
The Novva site will operate 72, identical, 4601 bhp, natural gas RICE, which utilize lean burn combustion
methods to deliver prime power to its data center. The following emission rates are proposed:
Table 5-1. Proposed Emission Rates
Pollutant Uncontrolled Emission Rate Emissions Reduction
Efficiency
Controlled Emission Rate
g/bhp-hr6 g/bhp-hr lb/hr
NOx 0.76 98.0% 0.0152 0.15
VOC 0.14 96.0%7 0.0056 0.05
PM 0.010 0% 0.01 0.10
CO 1.30 95.0%8 0.065 0.63
SO2 5.00E-03 0% 0.005 0.05

Novva has compared the above emission rates to available information in the following analyses.
5.3.1 Natural Gas Reciprocating Engines NOX Technologies
Step 1 – Identify All Reasonably Available Control Technologies
The following sources were reviewed to identify available control technologies:

► Comparative New Source Review (NSR) Permit Review;
► California Air Resources Board BACT Guidelines Tool;
► EPA’s RACT/BACT/LAER Clearinghouse RBLC Database9 for Natural Gas Generators (process type 17.130
Large Internal Combustion Engines [>500 hp] – Natural Gas)10; and
► EPA’s Air Pollution Control Technology Fact Sheets.

This search resulted in the following information:

6 Innio-Jenbacher specifications are based on a stack test performed and engineering calculations. 7 Note that this value has been communicated verbally with Novva, but further demonstration is required to achieve in practice as it represents beyond BACT. The control technology guarantee will be delivered to UDAQ following completion of
further testing.
8 Ibid.
9 Reasonably Available Control Technology (RACT)/Best Available Control Technology (BACT)/Lowest Achievable Emission Rate (LAER) 10 Database accessed April 2024.
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Table 5-2. Available Information Regarding NOx Emission Rates
Source Emission Rate Control Method Notes
RBLC 4.96 to 7.1 lb/hr
0.5 g/hp-hr
Good Combustion
Practices and
Compliance with Federal
Regulations
Conducted 04/02/2024 and filtered
to only display units between
2,600 and 6,000 hp
BAAQMD BACT
Guideline Lean
Burn (96.3.3)
0.07 g/bhp-hr

0.15 g/bhp-hr
SCR This first emission rate is listed as
technically feasible/economically
feasible. The second is listed as achieved in practice. The same control method is used in both cases.
SBCAPCD BACT
Guideline 3.5
(Lean Burn)
0.063 g/bhp-hr SCR This emission rate is listed as
achieved in practice.
Utah Municipal
Power Agency
Provo Power
Plant
0.53 lb/hr
(0.07 g/hp-hr)
SCR and Oxy-Cat
Emission Controls
G3520H Natural Gas Fired IC
Engine generators (August 2016)
Desert Power Electric Cooperative - Ft. Pierce Power Plant
0.07 g/bhp-hr (0.53 lb/hr) SCR and Oxidation Catalyst
Limited to 4,000 hr/yr
Permit Issued April 2022 G3520H Caterpillar Engines, 3,457
bhp, 4-stroke lean burn
Heber Light and Power Company - Power Plant
Unit #5: 3.00 lb/hr

Unit #13, 14: 0.54 lb/hr
Unit #5: Oxidation
Catalyst, limited hours of
operation

Unit #13,14: SCR and
Oxidation Catalyst,
limited hours of
operation
Permit Issued January 2024

Unit #5: 1550 KW, Unit # 13:
2631KW, Unit #14: 2550kW
Hurricane City
Power - Power Plant
0.50 g/bhp-hr (4.0
lb/hr)
Lean Burn with
Oxidation Catalyst, limited hours per year
Permit Issued October 2022
3628 bhp (2619 kW)
Santa Clara City Power 2154 kW: 3.18 lb/hr
2707 kW: 4.00 lb/hr
Oxidation Catalyst, limited hours of
operation
Permit Issued September 2021
Utah Municipal Power Agency
Nephi Power
Generation
Facility
0.07 g/bhp-hr (0.53
lb/hr)
SCR, and Oxidation
Catalyst
Permit Issued August 2023

3,457 hp

Available control technologies for natural gas, lean burn, reciprocating generator engines include the
following:

► Routine Maintenance;
► Good Combustion Practices;
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► Selective Catalytic Reduction (SCR) 11;
► Selective Non-Catalytic Reduction (SNCR);
► Low NOX Burners (LNB)/Low NOX Technology; and
► Pre-stratified charge.

The following step evaluates the technical feasibility of each of these options.
Step 2 – Eliminate Technically Infeasible Options
Routine Maintenance
Routine maintenance ensures the engine is working properly and as efficiently as possible, which, in turn,
helps reduce emissions. For spark ignition internal combustion engines, 40 CFR 60 Subpart JJJJ requires
that owners and operators of EPA-certified engines to operate and maintain the engine consistent with the
manufacturer’s emissions-related written instructions. Routine maintenance is considered technically
feasible.
Good Combustion Practices
Good combustion practices refer to the operation of engines at high combustion efficiency, which reduces
the products of incomplete combustion. The manufacturer will provide operation and maintenance manuals
that detail the required methods to achieve the highest levels of combustion efficiency for the proposed
unit. Use of good combustion practices is considered technically feasible.
Selective Catalytic Reduction
SCR systems introduce a liquid reducing agent such as ammonia or urea into the flue gas stream prior to a
catalyst. The catalyst then reduces the temperature needed to initiate the reaction between the reducing
agent and NOX to form nitrogen and water. SCR is considered technically feasible.
SNCR
SNCR uses a reagent of either NH3 or a urea solution, which is injected into the gas stream, to reduce NOX
to diatomic nitrogen and water. Depending on the reagent used, the optimum temperature range of the flue
gas is between 1,560 and 2,100 °F due to the lack of a catalyst to lower the activation energy of the
reactions. SNCR requires adequate mixing of NH3/urea with the combustion gases. The NOX reduction
reactions are driven by the thermal decomposition of NH3 or urea and the chemical reaction reduction of
NOX. Thus saying, this technology is less effective at lower levels of uncontrolled NOX. The optimum
temperature range for SNCR is between 1,560 and 2,100 °F. The gas exhaust from the engines at the
power plant typically is approximately 630 °F with low level of uncontrolled NOX. It would take more energy
to heat the exhaust downstream, which would generate more emissions of NOX. Thus, it is technically
infeasible to use the SNCR as a control technology on the power plant natural gas engines.
LNB/Low NOX Technology
LNBs and low NOX technology are designed to reduce NOX emissions by modifying the fuel combustion
process. The principle of all LNBs and low NOX technology is stepwise (i.e., staged) combustion and
localized exhaust gas recirculation (i.e., at the flame). LNBs and low NOX technology are designed to reduce
flame turbulence, delay fuel/air mixing, and establish fuel-rich zones for initial combustion. Low NOX
technology is technically feasible and will be included in the proposed engines’ designs.

11 NSCR was not evaluated as this techology is not compatiable with lean burn reciprocating engines and was thus not represented in the search conducted.
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Pre-stratified charge
Pre-stratified charge is a pre-combustion system that involves injecting air into the intake before entering
the combustion chamber. This allows the fuel-rich mixture away from the spark plug to be lean and lower
the combustion temperature in turn lowering the NOX emissions. It also allows the fuel-rich mixture near the
spark plug to be easily ignited. The engines at the power plant are lean engines not rich engines and
therefore this method is infeasible since it requires fuel rich mixtures.
Steps 3 - Step 5 – Select BACT
All technically feasible control technologies are proposed to achieve BACT for NOx emissions in natural gas
reciprocating generator engines:

► Routine Maintenance
► Good Combustion Practices
► SCR
► Low NOx Technology

This combination of technologies, as well as further engineering, allows Novva to propose an emission rate
of 0.0152 g/bhp-hr (0.15 lb/hr). This emission rate is lower than any other emission rate found in the
reviewed sources and thus Novva proposes that the proposed technologies meet BACT.
5.3.2 Natural Gas Engines CO Technologies
Step 1 – Identify All Reasonably Available Control Technologies
Novva reviewed the same sources outlined in Section 3.3.1 for Step 1 of CO BACT. Which resulted in the
following information:
Table 5-3. Available Information Regarding CO Emission Rates
Source Emission Rate Control Method Notes
RBLC 13.01 lb/hr
0.08 g/hp-hr
Good Combustion
Practices and
Compliance with
Federal Regulations
Conducted 04/02/2024 and filtered to
only display units between 2,600 and
6,000 hp
BAAQMD BACT Guideline Lean Burn (96.3.3)
0.1 g/bhp-hr 0.6 g/bhp-hr
Oxidation Catalyst This first emission rate is listed as technically feasible/economically feasible. The second is listed as
achieved in practice. The same control
method is used in both cases.
SBCAPCD
BACT
Guideline 3.5 (Lean Burn)
0.1 g/bhp-hr

0.45 g/bhp-hr
Oxidation Catalyst This first emission rate is listed as
technically feasible/economically
feasible. The second is listed as achieved in practice. The same control method is used in both cases.
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-7
Source Emission Rate Control Method Notes
Desert Power
Electric
Cooperative
- Ft. Pierce
Power
Plant
0.105 g/bhp-hr

0.8 lb/hr
SCR and Oxidation
Catalyst

Limited to 4,000 hr/yr
Permit Issued April 2022

G3520H Caterpillar Engines, 3,457
bhp, 4-stroke lean burn
Heber Light
and Power Company - Power Plant
Unit #5, 13, 14: 1.00
lb/hr
Unit #5: Oxidation
Catalyst, limited hours of operation
Unit #13,14: SCR and
Oxidation Catalyst,
limited hours of
operation
Permit Issued January 2024
Unit #5: 1,550 KW, Unit # 13: 2,631KW, Unit #14: 2,550kW
Hurricane
City Power
- Power
Plant
0.131 g/bhp-hr (1.0
lb/hr)
Lean Burn with
Oxidation Catalyst,
limited hours per year
Permit Issued October 2022

3,628 bhp (2619 kW)
Santa Clara
City Power
2,154 kW: 1.36 lb/hr

2,707 kW: 0.73 lb/hr
Oxidation Catalyst,
limited hours of
operation
Permit Issued September 2021
Utah Municipal Power Agency
Nephi
Power
Generation
Facility
0.11 g/bhp-hr (0.82
lb/hr)
SCR, and Oxidation
Catalyst
Permit Issued August 2023

3,457 hp

Available control technologies for natural gas, lean burn, reciprocating generator engines include the
following:

► Routine Maintenance/Good Combustion Practices;
► Thermal Oxidizer;
► NSCR; and
► Oxidation Catalyst.
Step 2 – Eliminate Technically Infeasible Options
Routine Maintenance/Good Combustion Practices
Routine maintenance and good combustion practices ensure the engine is working properly and as
efficiently as possible. The key to controlling CO emissions is efficient fuel combustion. Complete
combustion is achieved by having sufficient oxygen available to react with the fuel. Having excess oxygen
present will help achieve complete combustion, but will result in an increase in CO emissions. As discussed
under the NOx analysis, routine maintenance and good combustion practices are considered technically
feasible.
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-8
Thermal Oxidizer
Thermal oxidation increases the temperature of the flue as above the auto ignition temperature of CO and
other hydrocarbons, which is 1300 °F, to combust the air pollutants and reduce the CO emissions from the
power plant engines. This option requires a high level of CO and VOCs in the flue gas stream. Novva’s
proposed process does not have enough CO or VOCs in the exhaust stream and is therefore technically
infeasible.
NSCR
NSCR uses a catalyst to reduce carbon monoxide, nitric oxides, and hydrocarbons into carbon dioxide and
diatomic nitrogen. This technique does not require additional reagents like the SNCR process does because
the unburnt hydrocarbons are used as a reductant. NSCR is infeasible because it requires a high oxygen
content and this process does not have a high enough level to make this technological control system an
option.
Oxidation Catalysts
Oxidation catalysts convert unburned hydrocarbons (HC) and carbon monoxide (CO) into less harmful
products like carbon dioxide (CO2) and water through oxidation reactions with exhaust gas oxygen, and
work by oxidizing any oxidizable compound in an air stream. Oxidation catalysts are considered technically
feasible.
Steps 3 - Step 5 – Select BACT
All technically feasible control technologies are proposed to achieve BACT for NOx emissions in natural gas
reciprocating generator engines:

► Routine Maintenance/Good Combustion Practices
► Oxidation Catalyst in combination with SCR

This combination of technologies, as well as further engineering, allows Novva to propose an emission rate
of 0.065 g/bhp-hr (0.63 lb/hr) base on vendor communications. This emission rate is lower than any other
emission rate found in the reviewed sources and thus Novva proposes that the proposed technologies meet
BACT.
5.3.3 Natural Gas Reciprocating Engines VOC Technologies
Step 1 – Identify All Reasonably Available Control Technologies
Novva reviewed the same sources outlined in Section 3.3.1 for Step 1 of VOC BACT. Which resulted in the
following information:
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-9
Table 5-4. Available Information Regarding VOC Emission Rates
Source Emission Rate Control Method Notes
RBLC 1.25 to 5.9 lb/hr
0.176 g/bhp-hr
CO Oxidation
Catalyst, Good
Combustion
Practices and
Compliance with
Federal
Regulations
Conducted 04/02/2024 and filtered to
only display units between 2,600 and
6,000 hp

Some values may be reported with VOC
as NMHC + NOx
BAAQMD
BACT Guideline Lean Burn (96.3.3)
0.15 g/bhp-hr Oxidation Catalyst This emission rate is listed as achieved
in practice. POC has been assumed equivalent to VOC.
SBCAPCD BACT Guideline 3.5
(Lean Burn)
0.11 g/bhp-hr Oxidation Catalyst This emission rate is listed as achieved
in practice. ROC has been assumed
equivalent to VOC.
Desert Power Electric Cooperative - Ft. Pierce Power Plant
0.163 g/bhp-hr 1.24 lb/hr
SCR and Oxidation Catalyst Limited to 4,000
hr/yr
Permit Issued April 2022 G3520H Caterpillar Engines, 3,457 bhp, 4-stroke lean burn
Hurricane City Power - Power Plant
0.108 g/bhp-hr (0.9 lb/hr) Lean Burn with
Oxidation
Catalyst, limited
hours per year
Permit Issued October 2022

3628 bhp (2619 kW)
Santa Clara
City Power
2707 kW: 0.6 lb/hr Oxidation
Catalyst, limited
hours of
operation
Permit Issued September 2021
Utah
Municipal Power Agency Nephi Power Generation Facility
0.16 g/bhp-hr (1.22 lb/hr) SCR, and
Oxidation Catalyst
Permit Issued August 2023
3,457 hp

Available control technologies for natural gas, lean burn, reciprocating generator engines include the
following:

► Thermal Oxidizer;
► Non-selective Catalytic Reduction (NSCR);
► Oxidation Catalyst; and
► Good Combustion Practices.
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-10
Step 2 – Eliminate Technically Infeasible Options
Routine Maintenance/Good Combustion Practices
The key to controlling VOC emissions is efficient fuel combustion. Complete combustion is achieved by
having sufficient oxygen available to react with the fuel. Having excess oxygen present will help achieve
complete combustion, but will result in an increase in VOC emissions. Good combustion practices are
technically feasible and will be achieved by having proper equipment and proper training for all employees.
Thermal Oxidizer
Similar to as discussed in the CO BACT Analysis, this option is infeasible as it requires a high level of CO and
VOCs in the flue gas stream. Novva’s proposed process does not have enough CO or VOCs in the exhaust
stream per individual engine, and is therefore technically infeasible.
NSCR
Similar to as discussed in the CO BACT Analysis, NSCR is technically infeasible because it requires a high
oxygen content and Novva’s proposed process does not have a high enough level to make this technological
control system an option.
Oxidation Catalysts
Oxidation catalysts convert unburned hydrocarbons (HC) into less harmful products like carbon dioxide
(CO2) and water through oxidation reactions with exhaust gas oxygen, and work by oxidizing any oxidizable
compound in an air stream. As such, the use of an oxidation catalyst or catalytic oxidation is an effective
method for reducing VOC emissions, and is feasible for Novva’s proposed process.
Steps 3 - Step 5 – Select BACT
All technically feasible control technologies are proposed to achieve BACT for NOx emissions in natural gas
reciprocating generator engines:

► Routine Maintenance/Good Combustion Practices
► Oxidation Catalyst in combination with SCR

This combination of technologies, as well as further engineering, allows Novva to propose an emission rate
of 0.0056 g/bhp-hr (0.05 lb/hr). This emission rate is lower than any other emission rate found in the
reviewed sources and thus Novva proposes that the proposed technologies meet BACT.
5.3.4 Natural Gas Reciprocating Engines PM Technologies
Step 1 – Identify All Reasonably Available Control Technologies
Novva reviewed the same sources outlined in Section 3.3.1 for Step 1 of PM BACT. Which resulted in the
following information:
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-11
Table 5-5. Available Information Regarding PM Emission Rates
Source Emission Rate Control Method Notes
RBLC 0.003 to 0.5 lb/hr Good Combustion Practices
Conducted 04/02/2024 and
filtered to only display units
between 2,600 and 6,000
hp

These values are
representative of both PM2.5 and PM10
BAAQMD BACT Guideline Lean Burn (96.3.3)
Not Listed Natural Gas
SBCAPCD BACT
Guideline
3.5 (Lean
Burn)
80 ppmv total sulfur
and 4 ppmv H2S Natural Gas

Available control technologies for natural gas reciprocating generator engines include the following:

► Good Combustion Practices;
► Low Sulfur Natural Gas as Fuel
Step 2 – Eliminate Technically Infeasible Options
Good Combustion Practices
The particulate matter produced from natural gas reciprocating engines comes from three sources:

1) Trace amounts of metals and non-combustible inorganic material;
2) Semi-volatile organics which result from volatized lubricating oil or engine wear; and
3) Products of incomplete combustion.12

Novva is proposing to purchase natural gas from Kern River Gas’ Dry Lake (South) location. Novva has
contracted a reputable natural gas supplier, thus ensuring that the amount of metals and other non-
combustible inorganic material remains at a minimum.

Engine wear and volatilized lubricating oil are controlled through adherence to the manufacturer's operation
and maintenance procedures. It should be noted that additional lubricating oil is required for the operation
of the SCR and oxidation catalyst controls proposed in previous sections.13

Incomplete combustion products are limited through the use of the ideal air-fuel ratios as well as optimal
temperature ranges.

12 AP-42 Section 3.2 Natural Gas-Fired Reciprocating Engines, Subsection 3.2.2 Emissions 13 INNIO Jenbacker report issued for the Voltagrid Utah project on Feburary 28, 2024.
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-12

Use of good combustion practices for the proposed engines is considered technically feasible.
Use of Natural Gas as Fuel
Using clean, high-quality fuel that burns efficiently helps minimize PM formation due to its lower sulfur
content. Novva is proposing to purchase natural gas from Kern River Gas’ Dry Lake (South) location who is
guaranteeing a maximum total sulfur content of 0.05 gr/100scf. Use of natural gas for the proposed engines
is considered technically feasible.
Steps 3 - Step 5 – Select BACT
All technically feasible control technologies are proposed to achieve BACT for PM emissions in natural gas
reciprocating generator engines:

► Good Combustion Practices
► Use of High-Quality Natural Gas

This combination of technologies allows Novva to propose an emission rate of 0.01 g/bhp-hr (0.1 lb/hr).
Novva proposes that this emission rate meets BACT as it utilizes all available control technologies.
5.3.5 Natural Gas Reciprocating Engines SO2 Technologies
Step 1 – Identify All Reasonably Available Control Technologies
Novva reviewed the same sources outlined in Section 3.3.1 for Step 1 of SO2 BACT. Which resulted in the
following information:

Table 5-6. Available Information Regarding SO2 Emission Rates
Source Emission Rate Control Method Notes
RBLC 0.0029 lb/hr Not Listed Conducted 04/02/2024 and filtered to only display units between 2,600 and 6,000 hp.
BAAQMD BACT Guideline Lean Burn
(96.3.3)
Not Listed Natural Gas
SBCAPCD BACT Guideline 3.5 (Lean Burn)
80 ppmv total sulfur and 4ppmv H2S Natural Gas

Available control technologies for natural gas reciprocating generator engines include the following:

► Low Sulfur Natural Gas as Fuel
► Good Combustion Practices
NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants 5-13
Step 2 – Eliminate Technically Infeasible Options
Low Sulfur Natural Gas as Fuel
Using clean, high-quality fuel that burns efficiently helps minimize SO2 formation due to its lower sulfur
content. Novva is proposing to purchase natural gas from Kern River Gas’ Dry Lake (South) location who is
guaranteeing a maximum total sulfur content of 0.05 gr/100scf. Use of natural gas for the proposed engines
is considered technically feasible.
Good Combustion Practices
Similar to other pollutants, routine maintenance/good combustion practices ensure complete combustion.
With lack of sulfur in the fuel, less SO2 will be generated.
Steps 3 - Step 5 – Select BACT
All technically feasible control technologies are proposed to achieve BACT for SO2 emissions in natural gas
reciprocating generator engines:

► Use of High-Quality Natural Gas
► Good Combustion Practices

This combination of technologies allows Novva to propose an emission rate of 0.005 g/bhp-hr (0.05 lb/hr).
Novva proposes that this emission rate meets BACT as it utilizes all available control technologies.

5.3.6 Natural Gas Reciprocating Engines Ammonia Considerations
Increased ammonia emissions from these units are the result of ammonia slip from the SCR controls. The
only control method currently established for the minimization of these emissions is the use of Programable
Logic Controllers (PLC). The PLCs are designed to measure the NOx and Ammonia emission rates as a
process monitor in real time and then adjust the ammonia injection rate accordingly to maximize control of
NOx while minimizing NH3 slip. PLCs will be associated with the SCR control technology previously proposed.

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 6-1 Trinity Consultants
6. EMISSION IMPACT ANALYSIS
6.1 Comparison to Modeling Thresholds
Table B-1 in Appendix B compares total proposed emissions of each criteria pollutant to applicable modeling
thresholds contained in R307-403-4 through 7, and R307-410-4. As shown in Table B-1, the total emissions
for PM10, NOx, and CO exceed UDAQ modeling thresholds. Air dispersion modeling has been conducted and
a modeling report has been included in Appendix C of this application.

The natural gas RICE are subject to NESHAP ZZZZ and, per UDAQ guidance, are not required to complete
air dispersion modeling for HAPs per UDAQ guidance.
6.2 Source Size Determination
As presented in Table B-1, the potential to emit of all criteria pollutants are less than the respective NSR
major source emission thresholds (MST) (i.e., 250 tons for any criteria pollutant with exception to direct
PM2.5 and its precursors for which the MST is 70 tpy);14 however, the post project potential to emit for CO
will be greater than the Title V major source threshold (100 tpy). The potential to emit for formaldehyde
and total HAPs exceed the respective MSTs (i.e., 10 tons for any single HAP, and 25 tons for all HAPs
combined). Therefore, the proposed project will make the facility a Title V major source.

14 The proposed facility will be located in the Salt Lake PM2.5 nonattainment area. Per R307-403-5(2)(b)(i), the major source threshold is 70 tpy for direct PM2.5 and its precursors (NOX, SO2, VOCs, and NH3).

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 7-1 Trinity Consultants
7. OFFSET REQUIREMENTS
The Project is within an area of Salt Lake County which is currently designated as a Serious NAA of the 2006
24-hour NAAQS for PM2.5, a Moderate NAA of SO2, and a Moderate NAA of the 2015 8-hour NAAQS for
ozone.

PM2.5 Offsets
PM2.5 offsets are required for sources located in serious nonattainment areas that are a major source of
PM2.5 (i.e., 70 tpy of direct PM2.5 or individual PM2.5 precursors) or have a major modification of an existing
major source with an emissions increase greater than 10 tpy of direct PM2.5, 40 tpy of SO2, 40 tpy of NOx, or
40 tpy of VOC.15 The proposed project does not exceed MSTs for PM2.5 (as shown in Appendix Table B-1);
therefore, the PM2.5 offsets are not required for the proposed project.

PM10 Offsets
PM10 offsets or emission reduction credits (ERCs) are required for sources located within Salt Lake or Utah
County which have the potential to emit or cause an increase in NOX or SO2 greater than or equal to 25
tpy.16 The proposed facility is located within Salt Lake County, and the Project will result in an increase in
NOX exceeding the ERC thresholds (as shown in Appendix Table B-1). According to R307-421, for a total
NOX emission increase of 25 tpy or greater but less than 50 tpy, an emission offset ratio of 1:1 is required. 20
As the projected NOX emission increase is 46.37 tpy, Novva intends to purchase 47 tons of NOX ERCs from
the Salt Lake County PM10 and Ozone ERC Registry and apply them to this NOI air permit application.
Ozone Offsets
Ozone offsets are applicable to major sources of VOCs or NOX to sources located within an ozone non-
attainment area and to minor sources located in or, per R307-420-3, impacting Davis or Salt Lake
County and that have total VOC emission greater than 50 tpy. As the source is not a major source of
VOC or NOX and does not have VOC emissions greater than 50 tpy, ozone offsets are not applicable at
this time.17

15 UAC R307-403-5(2)(c)
16 UAC R307-421-3(1) 17 UAC R307-420-1(a)

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-1 Trinity Consultants
8. APPLICABLE REGULATIONS
This section includes a discussion of Federal and State requirements and their applicability to the project.
Regulations evaluated include NAAQS, State Implementation Plans (SIP), NSPS, and National Emission
Standards for Hazardous Air Pollutants (NESHAP) and Utah Air Quality Regulations. Novva has evaluated the
applicability of the aforementioned regulatory measures associated with the project’s proposed installations
described in this NOI air permit application. Applicable regulatory measures associated with the project
described in this report will be discussed in the subsequent sections.
8.1 Utah Air Quality Regulations
Novva has evaluated the applicability of each rule under the UAC Title R307. Applicable rules associated
with the installations described in this NOI will be discussed in the subsequent sections. The applicability of
modeling and offset rules has been addressed in previous sections of this report.
Table 8-1. Evaluation of UDAQ Air Quality Rules
Reference Regulation Name Applicability
Yes No
R307-101 1
General Requirements X
R307-102 1 General Requirements: Broadly Applicable
Requirements X
R307-103 1 Administrative Procedures X
R307-104 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

General Penalty Policy X

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-2 Trinity Consultants
Reference Regulation Name Applicability
Yes No
R307-135 Enforcement Policy for Asbestos Hazard Emergency Response Act X
R307-150 1 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
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 2 Standards of Performance for New Stationary Sources X
R307-214 2 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 Incinerator 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
R307-250 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

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-3 Trinity Consultants
Reference Regulation Name Applicability
Yes No
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
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
R307-320
Ozone Maintenance Areas and Ogden City: Employer Based Trip Reduction 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 Appliance Surface Coatings X
R307-348 Magnet Wire Coatings X
R307-349 Flat Wood Panel Coating X
R307-350 Misc. Metal Parts and Product Coating X
R307-351

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

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-4 Trinity Consultants
Reference Regulation Name Applicability
Yes No
R307-354 Automotive Refinishing Coatings X
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 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

Visibility X
R307-410 3 Permits: Emission Impact Analysis X
R307-414 1 Permits: Fees for Approval Orders X
R307-415

Permits: Operating Permit Requirements X
R307-417 Permits: Acid Rain Sources X
R307-420
Permits: Ozone Offset Requirements in Salt Lake
County and Utah County X
R307-421 4 Permits: PM10 Offset Requirements in Salt Lake
County and Utah County X
R307-424 Permits: 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 the Facility; however, this rule is not specific to operational compliance requirements, and is therefore not discussed in this NOI air permit application.
2. Applicable NSPS and NESHAP regulations are detailed under appropriate project headings.
3. The Emissions Impact Analysis is provided in Section 6 and was completed in accordance with the requirements
outlined in UAC R307-410.
4. The emissions offset requirements are discussed in detail in Section 7.
8.1.1 UAC R307-107 General Requirements: Breakdowns
The owner or operator of a source shall report breakdowns to the Director within 24 hours of the incident
via telephone, electronic mail, fax, or other similar method. A detailed written description of the

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-5 Trinity Consultants
circumstance of the incident including a corrective program directed at preventing future such incidents,
shall be submitted within 14 days of the onset of the incident. Novva will report breakdowns within 24 hours
via telephone, electronic mail, fax, or other similar method and provide a detailed written description within
14 days of the onset of an incident to UDAQ.
8.1.2 UAC R307-165: Emission Testing
The owner or operator of an emission unit shall conduct stack testing at least every five years and may be
required to test more frequently as required by a federal rule, approval order, or State Implementation Plan.
DAQ may also require more frequent testing to determine compliance status if they believe an emission limit
is being exceeded. Stack testing must be conducted within 180 days of emission unit start up. Unless
otherwise specified, DAQ must be notified of the date, time, and place of stack testing 30 days prior to the
stack test. A copy of the source test protocol must also be provided to DAQ at this time. DAQ must approve
the protocol prior to conducting the test. Testing protocol must include the reason for the test, the proposed
testing methodology, identify each stack to be tested, and identify each testing procedure to be used. If
required by DAQ, the owner or operator shall attend a pretest conference.

Stack testing shall be conducted under normal operating conditions and shall only burn fuels, use raw
materials, or maintain process conditions representative of normal operations. The production rate during
stack testing must be at least 90% of the maximum production rate, if this is not achievable than the
maximum production rate shall be 110% of the test achieved rate. The owner or operator shall request a
higher production rate when necessary and testing for that rate is successful. A written report of the results
from the stack testing is due to DAQ within 60 days of the completion of stack testing. The report must
include the testing results and all supporting information. DAQ may reject the stack testing results if they
determine the report and/or testing was incomplete, inadequate, not representative of operations, or the
director wasn’t provided the opportunity to have an observer at the test.
8.1.3 UAC R307-201: Emission Standards: General Emission Standards
Visible emissions from installations constructed after April 25, 1971 shall not exceed 20% opacity except as
otherwise provided in these rules. Visible emissions that exceed 20% for short periods (less than three
minutes) as the result of initial warm-up, cooling, etc. that is caused by facility startup or shutdown,
installation or operation shall not be deemed a violation if proper control technology is applied. The owner
or operator must minimize visible and non-visible emissions during these periods.

8.1.4 UAC R307-325: Ozone Nonattainment and Maintenance Areas: General
Requirements
No person that owns or operates a source located in a nonattainment or maintenance areas for ozone shall
allow or cause volatile organic compounds (VOCs) to be handled or stored in any manner that would result
in greater evaporation of VOCs than would have occurred if reasonably available control technology (RACT)
was applied.

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-6 Trinity Consultants
8.2 Federal Regulations
8.2.1 NSPS Subpart A (General Provisions)
All affected sources subject to an NSPS are also subject to the general provisions of NSPS Subpart A unless
specifically excluded by the source-specific NSPS. NSPS Subpart A requires the following of facilities subject
to a source-specific NSPS:

► Initial construction/reconstruction notification18
► Initial startup notification19
► Increased emission rate notification20
► Performance tests21
► Performance test date initial notification22
► General monitoring requirements23
► General recordkeeping requirements24
► Semiannual monitoring system and/or excess emission reports25

Novva will comply with all applicable requirements detailed above.
8.2.2 NSPS Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal Combustion Engines)
NSPS Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines,
establishes requirements for stationary spark ignition internal combustion engines for which construction,
modification, or reconstruction commenced after June 12, 2006.

The provisions of this subpart are applicable to owners and operators of spark ignition internal combustion
engines which commenced construction after June 12, 2006 and were manufactured after July 1, 2007. The
construction date is the date the engine was ordered by the owner or operator. The proposed generator
engines will be constructed after the specified construction dates. NSPS JJJJ is applicable to the generator
engines on site.
Emission Limitation
► Stationary SI ICE with a maximum engine power greater than or equal to 75 KW must comply with the
emission standards found in Table 1 §60.4233.26
► These limitations must be met for the life of the engine.27

18 40 CFR 60.7(a)(1)
19 40 CFR 60.7(a)(3) 20 40 CFR 60.7(a)(4) 21 40 CFR 60.8 22 40 CFR 60.7(a)(6)
23 40 CFR 60.13
24 40 CFR 60.7(b)
25 40 CFR 60.7(c)
26 40 CFR 60.4233(e). 27 40 CFR 60.4234.

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-7 Trinity Consultants
Compliance Requirements
► Purchase an engine certified according to procedures specified in this subpart, for the same model year
and demonstrating compliance according to one of the methods specified in paragraph (a) of this
section;28 or
► Purchase a non-certified engine and demonstrating compliance with the emission standards specified in §
60.4233(e) and according to the requirements specified in § 60.4244, as applicable, and according to
paragraphs (b)(2)(i) and (ii) of this section;29
• Keep a maintenance plan and records of conducted maintenance and must maintain and operate the
engine in a manner consistent with good air pollution control practice for minimizing emissions. In
addition, conduct an initial performance test and conduct subsequent performance testing every
8,760 hours or 3 years, whichever comes first; thereafter, to demonstrate compliance.30
► SI natural gas fired engines may operate using propane for a maximum of 100 hours per year as an
alternative fuel solely during emergency operations, but must keep records of such use. If propane is
used for more than 100 hours per year in an engine that is not certified to the emission standards when
using propane, the owners and operators are required to conduct a performance test to demonstrate
compliance with the emission standards of § 60.4233.31
► Air-to-fuel ratio controllers must be used with the operation of three-way catalysts/non-selective catalytic
reduction. The AFR controller must be maintained and operated appropriately in order to ensure proper
operation of the engine and control device to minimize emissions at all times.32
► Purchasing an engine certified according to procedures specified in this subpart, for the same model
year;33
► Keep a maintenance plan and records of conducted maintenance and maintain and operate the engine in
a manner consistent with good air pollution control practice for minimizing emissions.34
► Operate the emergency stationary ICE for no more than 100 hours per calendar year for testing and
maintenance, periods where there is a deviation of voltage or frequency of 5 percent or greater below
standard, and/or up to 50 hours per calendar year in non-emergency situations.35 There is no time limit
on the use of an emergency stationary ICE in emergency situations.36
► Owners and operators of stationary SI natural gas fired engines may operate their engines using propane
for a maximum of 100 hours per year as an alternative fuel solely during emergency operations, but must
keep records of such use.37

Recordkeeping38
► Must keep records of all notifications submitted to comply with this subpart and all supporting
documentation and records of maintenance conducted on the engine.
► Novva will also retain records to indicate that the engine is certified to the emission standards required
for the appropriate manufacture year and size.

28 40 CFR 60.4243(b)(1).
29 40 CFR 60.4243(b)(2).
30 40 CFR 60.4243(b)(2)(ii). 31 40 CFR 60.4243(e). 32 40 CFR 60.4243(g). 33 40 CFR 60.4243(b)(1)
34 40 CFR 60.4243(b)(2)(i)
35 40 CFR 60.4243(d)(2)
36 40 CFR 60.4243(d)(1)
37 40 CFR 60.4243(e) 38 40 CFR 60.4245.

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-8 Trinity Consultants
8.2.3 NESHAP Subpart A (General Provisions)
All affected sources are subject to the general provisions of Part 63 NESHAP Subpart A, unless specifically
excluded by the source-specific NESHAP. These provisions include initial notification and performance
testing, recordkeeping, and monitoring requirements for all other subparts, as applicable.
8.2.4 NESHAP SUBPART ZZZZ (NESHAP for Stationary Reciprocating Internal
Combustion Engines)
NESHAP Subpart ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary
Reciprocating Internal Combustion Engines, applies to stationary RICE at major and area sources of HAPs.
Subpart ZZZZ establishes requirements to demonstrate initial compliance and continuous compliance with
emission limitations and operating limits.39 The Novva Data Center is currently an area source that will
become a major source of HAPs, as the project’s HAP emissions are greater than ten (10) tons per year for
an individual HAP, and greater than twenty-five (25) tons per year of total HAPs. For the purposes of
regulatory applicability, the engines associated with the proposed project are greater than 500 BHP and are
four-stroke lean burn (4SLB) engines. Per 40 CFR 63.6590(a)(2)(iii), a stationary RICE at an existing area
source of HAPs is new if construction commenced after June 12, 2006. The following requirements have
been summarized for the installation of the reciprocating natural gas engines proposed to be installed.

Emissions & Operating Limitations
► During startup, the owner/operator of the RICE must minimize engine idle and limit the start-up period to
less than 30 minutes. After 30 minutes, the non-startup emissions limits apply.40
► Non-startup emissions limitations require that owners and operators of 4SLB RICE engines with greater
than 500 breaking horsepower reduce CO emissions by 93% or more or limit formaldehyde in exhaust to
14 ppmvd or less (@15% O2) per 40 CFR 63.6600(b).41
► For oxidation catalyst, maintain the pressure drop across catalyst within 2 inches of water (at 100% load
+/- 10%) from pressure measured during the initial performance test AND maintain catalyst inlet temp
between 450 and 1,350°F (based on 4-hr rolling avg.).42 An owner or operator can petition for different
temperature range. An owner or operator must install continuous parameter monitoring system (CPMS)
to continuously monitor and record catalyst inlet temperature and must measure pressure drop monthly
to show compliance.

Testing and Compliance Demonstration
► Initial performance testing is required within 180 days after startup per 40 CFR 63.6610 and semi-
annually thereafter for CO and O2 as applicable.43
► Performance testing must be completed in accordance with all requirements in 40 CFR 63.6620, which
requires compliance with Table 3 and 4.44
► The Notification of Compliance status must be submitted with the results of the initial compliance
demonstration in accordance with the requirements in 40 CFR 63.6645.45

39 40 CFR 63.6580 40 40 CFR 63.6625(h) 41 Per Table 2a of Subpart ZZZZ of 40 CFR Part 63
42 Per Table 2b of Subpart ZZZZ of 40 CFR Part 63
43 40 CFR 63.6640
44 40 CFR Table 3 – Requires subsequent tests semiannually for CO, O2, and moisture, which can be reduced to annually if compliance is demonstrated for two (2) consecutive years. 45 40 CFR 63.6630(c).

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application 8-9 Trinity Consultants
► Deviations from the emission and operating limitations that occur within the first 200 hours of operation
from engine start-up for new stationary RICE are not violations.46
► The semi-annual compliance reports shall be submitted per 40 CFR 63.6650, and any instances in which
the emission or operating limitation must be reported.

Notification Requirements47
► Provide Initial Notification within 120 days of becoming subject to this subpart.
► Submit a Notification of Intent to conduct a performance test at least 60 days prior to the scheduled test.
► Submit a Notification of Compliance Status, including the performance testing results, within 60 days of
the performance test.

46 40 CFR 63.6640(d) 47 40 CFR 63.6645

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants
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/produced3.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.
iJoc.i-iirKji'il Dale:' (X!/AS,‘2C U
DAQ 2018-002271
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:
____________________________
____________________________
____________________________
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):____________________________
____________________________
____________________________
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:
NAD83, Zone 12
DAO 2018 002272
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.
Installation of 72 natural gas reciprocating internal combustion engines, which will power generators
intended to provide primary power for the site's two proposed new data center buildings. Each engine willbe equipped with high efficiency control technology.
Doc.uim:i'ii D^lc: 02/28/2018
DAQ 2018-002274
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
See NOI Appendix B.
See NOI Appendix B.
See NOI Appendix B.
Jccumonl Dcjlc: 02/28/2018
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________ Form 11
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
Proposed site operating range _____________________________ hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: □ Yes □ No
5. Are you on an interruptible gas supply:
□Yes □ No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ BTU/hr
Oil Firing
9. Type of oil:
Grade number □ 1 □ 2 □ 4 □ 5 □ 6 Other specify ___________
10. Annual consumption: ______________ gallons 11. Heat content:______________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight
14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr
16. Direction of firing: □ horizontal □ tangential □ other: (specify)
Page 1 of 4 
Novva SLC Common, LLC.
West Jordan Data Center
Jenbacher
JGS 620 J715 24
7
5252
24
7
4,387.57
4,601
26,027,857 24,820,497.72
225.75
Date: May 30, 2024
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□Emergency Generator
□Driving pump/compressor
□Exhaust heat recovery
□Other (specify) ________________________
18. Cycle
□Simple cycle
□Regenerative cycle
□Cogeneration
□Combined cycle
Emissions Data
19. Manufacturer’s Emissions in grams per hour (gr/hp-hr): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ Other (specify)____________
□Other low-NOx combustor □SCR catalyst □Steam injection
Additional Information
21. On separate sheets provide the following:
A.Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
C. All calculations used for the annual emission estimates must be submitted with this form to be deemed
complete.
D.All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using
SCREEN3.
E. If this form is filled out for a new source, forms 1 and 2 must be submitted also.
0.140.76
0.19
200 mW
1.3
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 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 manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF EMISSION PT. (6) EXIT DATA
NUMBER NAME COMPONENT OR AIR CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1.Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2.Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3.Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4.Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5.Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7.Supply additional information as follows if appropriate:(a)Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b)Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
See modeling report

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants
APPENDIX B. EMISSION CALCULATIONS
Power Generation NOI
Table B-1. Novva West Jordan Data Center
NOX NO2 CO PM10 PM2.5 SO2 VOC NH3 CO2e Total HAPs
Natural Gas Engines (g/bhp-hr factors)46.37 46.37 198.28 30.50 30.50 15.25 45.85 61.01 997,261 55.14
Project Totals 46.37 46.37 198.28 30.50 30.50 15.25 45.85 61.01 997,261 55.14
Currently Permitted PTE1 4.89 4.89 4.42 0.37 0.37 0.01 0.97 -3,115 0.03
Proposed PTE 51.26 51.26 202.70 30.87 30.87 15.26 46.82 3176.24 997,261 55.16
Major Source Thresholds2 70 70 250 250 70 70 50 70 100,000 10/25
Threshold Exceeded? No No No No No No No No Not Applicable Yes
Modeling Limits3 40 40 100 15 --40 --------
Threshold Exceeded?Yes Yes Yes Yes No No No No No --
Table B-2. Emission Reduction Credits
Project NOx Emissions Increase (tpy)46.37
Offset ratio1 1
Offsets required 47
1. The necessary offset ratio is determined by R307-421. If project emissions of NOX or SO2 exceed 25 tons per year (tpy), but remain under 50 tpy, the ratio is 1:1. If the emissions increase is in excess of 50 tpy, the offset ratio increase to 1.2:1.
PM10 Offsets
Unit Group Potential Annual Emissions Estimate (tpy)
1. Currently Permitted PTE is per reduction in emissions letter submitted 5/30/24 to amend AO DAQE-AN160660001-22.
2. Major source thresholds are defined by 40 CFR section 51.165(a)(1)(iv)(A).
3. Modeling Limit is stated in UDAQ Emissions Impact Assessment Guidelines under Table 1: Total Controlled Emission Rates for New Sources or Emissions Increase.
Novva SLC Common, LLC.Trinity Consultants 1 of 4
Power Generation NOI
Table B-3. Project Annual Potential HAP Emissions
Pollutant Project Change in Hourly
Emissions (lb/hr)
Project Change in Hourly
Emissions (tpy)
Benzene 8.56E-01 3.75
Toluene 7.93E-01 3.47
Xylenes 3.58E-01 1.57
Formaldehyde 5.29E+00 23.18
Acetaldehyde 6.50E-01 2.85
Acrolein 4.00E-01 1.75
Naphthalene 1.45E-01 0.63
1,1,2,2-Tetrachloroethane 3.11E-03 1.36E-02
1,1,2-Trichloroethane 2.47E-03 1.08E-02
1,3-Butadiene 5.19E-01 2.27
1,3-Dichloropropene 2.05E-03 8.99E-03
2-Methylnaphthalene 6.46E-02 0.28
2,2,4-Trimethylpentane 4.86E-01 2.13
Acenaphthene 2.43E-03 1.06E-02
Acenaphthylene 1.08E-02 4.71E-02
Benzo(b)fluoranthene 3.23E-04 1.41E-03
Benzo(e)pyrene 8.07E-04 3.53E-03
Benzo(g,h,i)perylene 8.05E-04 3.53E-03
Biphenyl 4.12E-01 1.81
Butyr/Isobutyraldehyde 7.86E-03 3.44E-02
Carbon Tetrachloride 2.85E-03 1.25E-02
Chlorobenzene 2.36E-03 1.04E-02
Chloroform 2.22E-03 9.71E-03
Chrysene 1.35E-03 5.90E-03
Ethylbenzene 7.72E-02 0.34
Ethylene Dibromide 3.45E-03 1.51E-02
Fluoranthene 2.16E-03 9.45E-03
Fluorene 1.10E-02 4.83E-02
Methanol 1.94E-01 0.85
Methylene Chloride 1.56E-03 6.81E-03
Hexane 2.16E+00 9.45
PAH 5.23E-02 0.23
Phenanthrene 2.02E-02 8.86E-02
Phenol 1.87E-03 8.18E-03
Pyrene 2.64E-03 1.16E-02
Styrene 4.59E-02 0.20
Tetrachloroethane 1.93E-04 8.45E-04
Vinyl Chloride 1.16E-03 5.08E-03
Novva SLC Common, LLC.Trinity Consultants 2 of 4
Power Generation NOI
Table B-4. Jenbaucher J 620 GS-J715 Natural Gas Engine Parameters
Parameter Value
Generator Make Jenbacher
Engine Model Number JGS 620 J715
Annual Hours of Operation (hr/yr)1 8,760
Total Number of Generators 72
Max Power Output (bhp)2 4,387.57
Fuel Consumption Flow Rate (scf/hr)23 25,771
Fuel Consumption in MMBTU/hr3 27.0055
Design Exhaust Flow Rate (scf/hr)2 394,215
Design Exhaust Temperature (F)2 748
Natural Gas Heat Content (Btu/scf)5 1,047.91
Fuel Natural Gas
1. Annual Hours of Operation assume continuous 24/7/365 operation.
2. Determined from the manufacturer specification sheet.
3. Maximum fuel consumption conservatively used.
4. Spec. Fuel consumption of engine (BTU/bhp-hr)
100% Load 5657
75% Load 585350% Load 6155
5. Gas Sample Heating value (but/scf)
Coyote Creek (north)1043.79
Dry Lake (south)1047.91
Table B-5. J 620 Criteria Pollutant Emission Factors
100%85%
25,771 21,905 NOx 98.00%
NOX 1 (g/bhp-hr)0.76 0.76 CO 95.00%
VOC1 (g/bhp-hr)0.14 0.14 CH2O 96.00%
PM101 (g/bhp-hr)0.010 0.010 VOC 96.00%
PM2.51 (g/bhp-hr)0.010 0.010 PM 0.00%
CO 1 (g/bhp-hr)1.30 1.30
SO2 1 (g/bhp-hr)5.00E-03 5.00E-03
NH31 (g/bhp-hr)0.02 0.02
CO22 (kg/MMBTU)53.06 53.06
CH42 (kg/MMBTU)1.00E-03 1.00E-03
N2O2 (kg/MMBTU)1.00E-04 1.00E-04
CO2e3 (kg/MMBTU)53.11 53.11
1. NOX, CO, VOC, PM, SO2 and NH3 emission factors per manufacturer specifications.
2. GHG Emission Factors from 40 CFR 98 Tables C-1 and C-2.
3. CO2e is the sum of GHG constituents multiplied by their
1 CO2 GWP
25 CH4 GWP
298 N2O GWP
Table B-7. J 620 Controlled Emission Rates
Uncontrolled Emission Rate
g/bhp-hr g/bhp-hr lb/hr
NOx 0.76 98.0%0.0152 0.15VOC0.14 96%0.0056 0.05PM0.010 0%0.01 0.10CO1.30 95%0.065 0.63SO25.00E-03 0%0.005 0.05
Table B-8. Total Criteria Pollutant Potential Emissions: Natural Gas Engines
NOX CO VOC PM10 PM2.5 SO2 CO2e NH3
Emissions per Engine (lb/hr)0.15 0.63 0.05 0.10 0.10 0.05 3162.29 0.19
All Engines Total (lb/hr)10.59 45.27 3.90 6.96 6.96 3.48E+00 227,685 13.93All Engines Total (tpy)46.37 198.28 45.85 30.50 30.50 15.25 997,261 61.01
Table B-6. J 620 Emissions Control Efficiency Emissions
Reduction EfficiencyPollutantPollutantUnitsData Center Generators1,2
Emissions Reduction EfficiencyPollutant Controlled Emission Rate
Potential Emissions
Novva SLC Common, LLC.Trinity Consultants 3 of 4
Power Generation NOI
Table B-9. HAP Potential to Emit: Natural Gas Engines
Pollutant1 Emission Factor (lb/MMbtu)1,2 Uncontrolled HAP Emissions per
Engine (lb/hr)3
Controlled HAP Emissions per
Engine (lb/hr)3
HAP Emissions
per Engine (tpy)4
Total Uncontrolled Individual HAP Emissions All Engines (tpy)
Total Controlled Individual HAP Emissions All Engines (tpy)
Also a VOC, not a HC?
1,1,2,2-Tetrachloroethane 4.00E-05 1.08E-03 4.32E-05 4.73E-03 3.41E-01 1.36E-02 Yes
1,1,2-Trichloroethane 3.18E-05 8.59E-04 3.44E-05 3.76E-03 2.71E-01 1.08E-02 Yes
1,3-Butadiene 2.67E-04 7.21E-03 7.21E-03 3.16E-02 2.27 2.27 No1,3-Dichloropropene 2.64E-05 7.13E-04 2.85E-05 3.12E-03 2.25E-01 8.99E-03 Yes2-Methylnaphthalene 3.32E-05 8.97E-04 8.97E-04 3.93E-03 2.83E-01 2.83E-01 No
2,2,4-Trimethylpentane 2.50E-04 6.75E-03 6.75E-03 2.96E-02 2.13 2.13 No
Acenaphthene 1.25E-06 3.38E-05 3.38E-05 1.48E-04 1.06E-02 1.06E-02 No
Acenaphthylene 5.53E-06 1.49E-04 1.49E-04 6.54E-04 4.71E-02 4.71E-02 No
Acetaldehyde 8.36E-03 2.26E-01 9.03E-03 9.89E-01 7.12E+01 2.85 Yes
Acrolein 5.14E-03 1.39E-01 5.55E-03 6.08E-01 4.38E+01 1.75 Yes
Benzene 4.40E-04 1.19E-02 1.19E-02 5.20E-02 3.75 3.75 No
Benzo(b)fluoranthene 1.66E-07 4.48E-06 4.48E-06 1.96E-05 1.41E-03 1.41E-03 No
Benzo(e)pyrene 4.15E-07 1.12E-05 1.12E-05 4.91E-05 3.53E-03 3.53E-03 No
Benzo(g,h,i)perylene 4.14E-07 1.12E-05 1.12E-05 4.90E-05 3.53E-03 3.53E-03 No
Biphenyl 2.12E-04 5.73E-03 5.73E-03 2.51E-02 1.81 1.81 No
Butyr/Isobutyraldehyde 1.01E-04 2.73E-03 1.09E-04 1.19E-02 8.60E-01 3.44E-02 Yes
Carbon Tetrachloride 3.67E-05 9.91E-04 3.96E-05 4.34E-03 3.13E-01 1.25E-02 Yes
Chlorobenzene 3.04E-05 8.21E-04 3.28E-05 3.60E-03 2.59E-01 1.04E-02 YesChloroform2.85E-05 7.70E-04 3.08E-05 3.37E-03 2.43E-01 9.71E-03 YesChrysene6.93E-07 1.87E-05 1.87E-05 8.20E-05 5.90E-03 5.90E-03 NoEthylbenzene3.97E-05 1.07E-03 1.07E-03 4.70E-03 3.38E-01 3.38E-01 NoEthylene Dibromide 4.43E-05 1.20E-03 4.79E-05 5.24E-03 3.77E-01 1.51E-02 YesFluoranthene1.11E-06 3.00E-05 3.00E-05 1.31E-04 9.45E-03 9.45E-03 NoFluorene5.67E-06 1.53E-04 1.53E-04 6.71E-04 4.83E-02 4.83E-02 NoFormaldehyde(See Footnote 2)1.84E+00 7.35E-02 8.05 5.80E+02 2.32E+01 YesMethanol2.50E-03 6.75E-02 2.70E-03 2.96E-01 2.13E+01 8.52E-01 YesMethylene Chloride 2.00E-05 5.40E-04 2.16E-05 2.37E-03 1.70E-01 6.81E-03 YesHexane1.11E-03 3.00E-02 3.00E-02 1.31E-01 9.45 9.45 NoNaphthalene7.44E-05 2.01E-03 2.01E-03 8.80E-03 6.34E-01 6.34E-01 NoPAH2.69E-05 7.26E-04 7.26E-04 3.18E-03 2.29E-01 2.29E-01 No
Phenanthrene 1.04E-05 2.81E-04 2.81E-04 1.23E-03 8.86E-02 8.86E-02 No
Phenol 2.40E-05 6.48E-04 2.59E-05 2.84E-03 2.04E-01 8.18E-03 Yes
Pyrene 1.36E-06 3.67E-05 3.67E-05 1.61E-04 1.16E-02 1.16E-02 No
Styrene 2.36E-05 6.37E-04 6.37E-04 2.79E-03 2.01E-01 2.01E-01 No
Tetrachloroethane 2.48E-06 6.70E-05 2.68E-06 2.93E-04 2.11E-02 8.45E-04 Yes
Toluene 4.08E-04 1.10E-02 1.10E-02 4.83E-02 3.47 3.47 No
Vinyl Chloride 1.49E-05 4.02E-04 1.61E-05 1.76E-03 1.27E-01 5.08E-03 Yes
Xylenes 1.84E-04 4.97E-03 4.97E-03 2.18E-02 1.57 1.57 No
579.59 23.18
745.63 55.14
1. HAPs and corresponding emissions factors from AP-42 Table 3.2-2.
2. Formaldehyde emission factor from manufacturer specifications:
0.19 g/bhp-hr
3. HAP emissions (lb/hr) = NG Flow Rate (scf/hr) * EF (lb/MMbtu) * Heating Content of NG (btu/scf) / 106.
4. HAP emissions (tpy) = HAP Emissions (lb/hr) * Annual Hours of Operation (hr/yr) / 2000 (lb/ton).
Total HAPs
Max HAP
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NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants
APPENDIX C. AIR DISPERSION MODELING REPORT
NOVVA SLC COMMON, LLC. MODELING REPORT
PM10 24-hour NAAQS, NO2 1-hour and Annual NAAQS,
and CO 1-hour and 8-hour NAAQS / Modeling Report
Novva SLC Common, LLC. / West Jordan Data Center

Prepared By:
TRINITY CONSULTANTS
4525 Wasatch Boulevard, Suite 200
Salt Lake City, UT 84124
[phone]

For:
Novva SLC Common, LLC.
6477 Wells Park Road
West Jordan, Utah 84081

May 2024

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants i
TABLE OF CONTENTS
1. INTRODUCTION 1-1
1.1 General Information ................................................................................................. 1-1
1.2 Project Scope ............................................................................................................ 1-1
1.3 Plant Layout .............................................................................................................. 1-1
2. AIR DISPERSION MODELING DESCRIPTION 2-1
2.1 Model Selection ......................................................................................................... 2-1
2.2 Meteorological Data .................................................................................................. 2-1
2.3 Terrain Elevations ..................................................................................................... 2-1
2.4 Receptors .................................................................................................................. 2-1
2.5 UTM Coordinate System ............................................................................................ 2-5
2.6 Building Downwash .................................................................................................. 2-5
3. NO2 SOURCE PARAMETERS AND EMISSION RATES 3-1 3.1 NO2 Point Source Parameters and Emission Rates .................................................... 3-1
3.1.1 Combustion Equipment Modeling Parameters and Emission Rates ................................ 3-1
3.1.2 Combustion Equipment Operating Parameters ........................................................... 3-1 3.2 Nearby NO2 Sources - Emission Rates ....................................................................... 3-2
4. PM10 SOURCE PARAMETERS AND EMISSION RATES 4-1
4.1 PM10 Point Source Parameters and Emission Rates ................................................... 4-1
4.1.1 Combustion Equipment Modeling Parameters and Emission Rates ................................ 4-1
4.1.2 Combustion Equipment Operating Parameters ........................................................... 4-1
4.2 Nearby PM10 Sources ................................................................................................. 4-1
5. CO SOURCE PARAMETERS AND EMISSION RATES 5-1
5.1 CO Point Source Parameters and Emission Rates ...................................................... 5-1
5.1.1 Combustion Equipment Modeling Parameters and Emission Rates ................................ 5-1
5.1.2 Combustion Equipment Operating Parameters ........................................................... 5-1
5.2 Nearby CO Sources .................................................................................................... 5-1
6. NO2 MODELING ANALYSIS 6-1 6.1 NO2 Special Processing ............................................................................................. 6-1 6.2 Background NO2 Concentrations ............................................................................... 6-1 6.3 Background Ozone Concentrations ........................................................................... 6-2 6.4 Modeled NO2 Concentration ...................................................................................... 6-2 6.5 NO2 NAAQS Analysis Results ..................................................................................... 6-3 6.6 NO2 Mitsubishi Method Analysis Results ................................................................... 6-5
7. PM10 MODELING ANALYSIS 7-1
7.1 Background PM10 Concentrations .............................................................................. 7-1
7.2 Modeled PM10 Concentration ..................................................................................... 7-1
7.3 PM10 NAAQS Analysis Results .................................................................................... 7-2
8. CO MODELING ANALYSIS 8-1
8.1 Background CO Concentrations ................................................................................. 8-1
8.2 Modeled CO Concentration ........................................................................................ 8-1
8.3 CO NAAQS Analysis Results ....................................................................................... 8-1
Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants ii
APPENDIX A. WEST JORDAN FACILITY MODELING PARAMETERS AND EMISSION RATES A-1

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 1-1
1. INTRODUCTION
1.1 General Information
Novva’s West Jordan facility (Facility) is a data center located at 6477 Wells Park Rd, West Jordan, UT
84081. Novva is proposing to modify the West Jordan Facility by installing seventy-two (72) natural gas-
fired generators to provide prime power to two (2) new data center buildings onsite: Building 2 and Building
3. In conjunction with this modeling report, Novva is submitting an NOI air permit application to UDAQ to
obtain an approval order (AO) for the proposed modification.

This modeling protocol and report outline the methodology that Novva has used in conducting air dispersion
modeling. It describes the results that demonstrate compliance with the NAAQS for one (1)-hour and annual
nitrogen dioxide (NO2), 24-hour PM with an aerodynamic diameter of less than 10 microns (PM10), and 1-
hour and 8-hour carbon monoxide (CO) at the Facility. Dispersion modeling has been conducted in
accordance with R307-410-3 and 40 Code of Federal Regulations (CFR) Part 51, Appendix W Guideline on
Air Quality Models.
1.2 Project Scope
Novva is proposing to modify the West Jordan Facility by installing seventy-two (72) natural gas-fired
generator engines to provide prime power to two (2) new buildings onsite: Building 2 and Building 3. The
natural gas-fired generator engines will be equipped with several high efficiency control technologies.

Equipment included in the 1-hour and annual NO2, 24-hour PM10, and 1-hour and 8-hour CO modeling
analysis of the West Valley Facility are as follows:
Existing Equipment
► Thirty-seven (37) Diesel-Fired Emergency Generator Engines; and
► One (1) Natural Gas-Fired Boiler.
Proposed Equipment
► Seventy-two (72) Natural Gas-Fired Generator Engines.
1.3 Plant Layout
The general facility layout is shown in Figure 1-1, below. Figure 1-2, also below, presents a basic layout of
the Facility. The natural gas-fired generator engines will supply prime power to Building 2 and Building 3.
The existing diesel-fired emergency generator engines supply emergency power to Building 1. The natural
gas-fired boiler provides comfort heating to the office building.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 1-2
Figure 1-1. West Jordan Facility Site Plan

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 2-1
2. AIR DISPERSION MODELING DESCRIPTION
This section describes the air quality dispersion modeling analysis performed to estimate the ambient air
impacts of Novva’s operation of the Facility. All modeling results were compared to both the NO2 NAAQS for
the 1-hour and annual averaging period, the PM10 NAAQS for the 24-hour averaging period, and the CO
NAAQS for the 1-hour and 8-hour averaging period. The objective of the NAAQS analysis is to demonstrate
through air quality dispersion modeling that emissions from the Facility do not cause or contribute to an
exceedance of the 1-hour/annual NO2 NAAQS, 24-hour PM10 NAAQS, or 1-hour/8-hour CO NAAQS. Four (4)
nearby offsite area sources were included at the direction of UDAQ. Dispersion Modeling was conducted in
accordance with R307-410-3 and 40 CFR Part 51, Appendix W Guideline on Air Quality Models.
2.1 Model Selection
Near-field dispersion modeling was performed using the latest version of the AERMOD modeling system,
version 23132, which is an EPA approved, steady-state Gaussian mathematical plume model. AERMOD is
composed of three (3) modular components: AERMAP, the terrain preprocessor that characterizes the
terrain and generates source and receptor elevations and surrounding hill height scales; AERMET, the
meteorological preprocessor that processes raw surface and upper air meteorological observations for use
by AERMOD; and AERMOD, the control module and modeling processor.
2.2 Meteorological Data
Meteorological data used in the dispersion modeling analysis was processed and provided by UDAQ.1 Data
consists of five (5) individual years (2017 through 2021) of National Weather Service (NWS) surface data
collected at the Salt Lake City Airport that were then concatenated into a five (5)-year file. Concurrent upper
air observations used in AERMET were obtained from the Salt Lake City Airport.
2.3 Terrain Elevations
Terrain elevations for the Facility’s sources, receptors and buildings were determined using National
Elevation Dataset (NED), the primary elevation data product of the United States Geologic Survey (USGS).2
NED data are distributed in geographic coordinates in units of decimal degrees, and in conformance with the
North American Datum of 1983 (NAD 83). The NED used for this analysis is at a resolution of 1/3 arc-
second (about 10 meter) grid spacing. Elevations were converted from the NED grid spacing to the air
dispersion model receptor spacing using the AERMOD preprocessor, AERMAP version 18081. All data
obtained from the NED files was checked for completeness and spot-checked for accuracy.
2.4 Receptors
A modeling domain was developed for the near-field analyses to encompass the location of the maximum
modeled concentration from Novva’s sources. Discrete receptor locations in AERMOD were based on UTM
coordinates in the NAD83 datum, Zone 12N. An initial modeling grid extending a minimum of 10.0
kilometers from the Facility center was established. The receptor grid was developed to ensure that
maximum pollutant concentrations were captured by the model. The Facility boundary is based on the
existing Facility boundary.
The model receptors consisted of boundary receptors and gridded receptors with the following spacing:

1 Email from Dave Prey, UDAQ, March 08, 2024. 2 NED data obtained at https://viewer.nationalmap.gov/basic/#/ downloaded August 14, 2023.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 2-2
► The ambient air boundary was placed at the Facility property line and consists of discrete receptors
placed at 25-meter intervals.
► The fine grid contains 50-meter spaced receptors extending to at least 950 meters from the center of
the Facility.
► The medium grid contains 100-meter spaced receptors extending to at least 2,200 meters from the
center of the Facility.
► The coarse grid contains 1,000-meter spaced receptors extending to 11 kilometers from the center of
the Facility.
► Additional receptors were placed on the neighborhood and road north of the facility at 25-meter
intervals.

Figure 2-1 and Figure 2-2 below show the ambient air boundary receptors (shown in purple below) and
gridded off-site receptors (yellow). Figure 2-2 does not show the full extent of the coarse-grid receptors, but
shows their spacing.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 2-3
Figure 2-1. Boundary Receptors

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 2-4
Figure 2-2. Fine, Medium, and Coarse Grid and Boundary Receptors

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 2-5
2.5 UTM Coordinate System
In all modeling analyses, input and output data files, the locations of emission sources, structures, and
receptors were represented in the Universal Transverse Mercator (UTM) coordinate system and based on
NAD83. In this grid, the world is divided into 60 north-south zones, each covering a strip 6° wide in
longitude. The general area of the site is located in UTM Zone 12N. In each UTM zone, coordinates are
measured north and east in meters. The northing values are measured continuously from zero at the
equator, in a northerly direction. A central meridian through the middle of each 6° zone is assigned an
easting value of 500,000 meters. Grid values to the east of this central meridian, as in the case of the site,
are greater than 500,000 meters.
2.6 Building Downwash
Emission sources were evaluated in terms of their proximity to nearby structures. The following structures
were included for the Building Profile Input Program (BPIP), which predicts the effects of building
downwash:

► Three (3) data center buildings;
• Building 1
• Building 2
• Building 3
► One (1) office building;
► Seventy-two (72) engine trailers; and
► Seventy-two (72) SCR housings.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 3-1
3. NO2 SOURCE PARAMETERS AND EMISSION RATES
3.1 NO2 Point Source Parameters and Emission Rates
All natural gas-fired generator engines, diesel-fired emergency generator engines, and the boiler were
modeled as point sources. The generator engines are all uncapped point sources and the boiler is a capped
point source. Each natural gas generator engine is equipped with several high efficiency control
technologies. All point sources require release height, stack temperature, stack velocity, and stack diameter.
This section explains the methodology to obtain the modelling parameters required for point sources. All
inputs for stack source parameters can be seen in Appendix A of this modeling analysis.
3.1.1 Combustion Equipment Modeling Parameters and Emission Rates
The modeled point sources of NO2 at the Facility consist of the equipment and their release parameters as
seen in Table 3-1. Stack information was taken from on-site equipment or manufacturers’ guarantees.
Table 3-1. Release Parameters for NO2 Point Sources
Unit Engine
Make
Stack
Height
(m)
Stack
Temp.
(K)
Stack
Velocity
(m/s)
Stack
Diameter
(m)
Natural Gas-Fired
Generator Engines
Jenbacher
J620 7.62 634.26 13.97 0.61
Diesel-Fired Emergency
Generator Engines
Cummins 12.80 751.48 42.37 0.46
MTU 1500 12.80 708.15 34.30 0.46
MTU 1750 12.80 738.15 36.70 0.46
MTU 2000 12.80 753.15 45.73 0.46
CAT 2.78 804.15 52.47 0.20
Kohler 12.80 773.15 58.07 0.46
Boiler - 2.44 435.93 7.45 0.15
3.1.2 Combustion Equipment Operating Parameters
Outside of emergency situations, the diesel-fired emergency generator engines will only operate for testing
and maintenance purposes. Novva has evaluated various operating scenarios in which operating and
maintenance may be conducted on the diesel-fired generators. Novva has determined groupings of diesel-
fired generator engines to be operated concurrently for operating and maintenance purposes. Table 3-2
outlines these groupings. All natural gas-fired generator engines and the boiler have been modeled as
operating 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario. The operating
scenarios are reflected in the corresponding modeling files submitted with this report.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 3-2
Table 3-2. Diesel-Fired Emergency Engine Operating Groups
Operating Scenario Source Group Source 1 Source 2
7 AM – 7 PM NOFF OFFICE -
7 AM – 7 PM NS1G1 GENN01 GENN02
7 AM – 7 PM NS1G2 GENN03 GENN04
7 AM – 7 PM NS2G1 GENN05 GENN06
7 AM – 7 PM NS2G2 GENN07 GENN08
7 AM – 7 PM NS3G1 GENN09 GENN10
7 AM – 7 PM NS3G2 GENN11 GENN12
7 AM – 7 PM NS4G1 GENN13 GENN14
7 AM – 7 PM NS4G2 GENN15 GENN16
7 AM – 7 PM NS5G1 GENN17 GENN18
7 AM – 7 PM NS5G2 GENN19 GENN20
7 AM – 7 PM NS6G1 GENN21 GENN22
7 AM – 7 PM NS6G2 GENN23 GENN24
7 AM – 7 PM NS7G1 GENN25 GENN26
7 AM – 7 PM NS7G2 GENN27 GENN28
7 AM – 7 PM NS8G1 GENN29 GENN30
7 AM – 7 PM NS8G2 GENN31 GENN32
7 AM – 7 PM NS10G1 GENN33 GENN34
7 AM – 7 PM NS10G2 GENN35 GENN36
3.2 Nearby NO2 Sources - Emission Rates
Nearby NO2 sources included in models of the Nephi Facility consist of the following, as received from
UDAQ:3
Nearby Point Source IDs
► SLC1_G02
► SLC1_G03
► SLC1_G04
► SLC1_G05
► SLC2_G14
► HEATEXCH
► BOILER4
► SLC3_G30
► SLC3_G32
► STCK1
► STCK2
► STCK3
► STCK4
► STCK5
► STCK6
► STCK7
► STCK8
► STCK9
► STCK10
► STCK11
► STCK12
► STCK1NL
► STCK2NL
► STCK3NL
► STCK4NL
► STCK5NL
► STCK6NL
► STCK7NL
► STCK8NL
► STCK9NL
► STCK10NL
► STCK11NL
► STCK12NL
► GEN
► PLASMA96
► PLASMA60
► FICEP
► ROBOT
► PLASMA20
► OA_FPUMP
Nearby Volume Source IDs
► WELDING

3 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 4-1
4. PM10 SOURCE PARAMETERS AND EMISSION RATES
4.1 PM10 Point Source Parameters and Emission Rates
All natural gas-fired generator engines, diesel-fired emergency generator engines, and boiler were modeled
as point sources. The generator engines are all uncapped point sources and the boiler is a capped point
source. All point sources require release height, stack temperature, stack velocity, and stack diameter. This
section explains the methodology to obtain the modelling parameters required for point sources. All inputs
for stack source parameters can be seen in Appendix A of this modeling analysis.
4.1.1 Combustion Equipment Modeling Parameters and Emission Rates
The modeled point sources of PM10 at the Facility consist of the same equipment and associated release
parameter as detailed in Section 3.1.1 of this report.
4.1.2 Combustion Equipment Operating Parameters
All natural gas-fired generator engines and the boiler have been modeled as operating 24 hours per day, 7
days a week, 52 weeks a year in each operating scenario. The diesel-fired emergency generator engines will
follow the operating scenarios as described in Section 3.1.2 of this report. However, the PM10 emissions
from the diesel-fired emergency generator engines were conservatively modeled according to the following
scenario:

► All diesel-fired emergency generator engines operating together any time between 7:00 AM and 7:00
PM.

Section 7.3 of this report shows that the PM10 model meets the NAAQS with this conservative operating
scenario. As such, modeling the diesel-fired emergency generator engine’s individual groupings was not
required.
4.2 Nearby PM10 Sources
No nearby sources of PM10 were required to be included as part of this model.4

4 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 5-1
5. CO SOURCE PARAMETERS AND EMISSION RATES
5.1 CO Point Source Parameters and Emission Rates
All natural gas-fired generator engines, diesel-fired emergency generator engines, and boiler were modeled
as point sources. The generator engines are all uncapped point sources and the boiler is a capped point
source. Each natural gas generator engine is equipped with several high efficiency control technologies. All
point sources require release height, stack temperature, stack velocity, and stack diameter. This section
explains the methodology to obtain the modelling parameters required for point sources. All inputs for stack
source parameters can be seen in Appendix A of this modeling analysis.
5.1.1 Combustion Equipment Modeling Parameters and Emission Rates
The modeled point sources of CO at the Facility consist of the same equipment and associated release
parameter as detailed in Section 3.1.1 of this report.
5.1.2 Combustion Equipment Operating Parameters
All natural gas-fired generator engines and the boiler have been modeled as operating 24 hours per day, 7
days a week, 52 weeks a year in each operating scenario. The diesel-fired emergency generator engines will
follow the operating scenarios as described in Section 3.1.2 of this report. However, the CO emissions from
the diesel-fired emergency generator engines were conservatively modeled according to the following
scenario:

► All diesel-fired emergency generator engines operating together any time between 7:00 AM and 7:00
PM.

Section 8.3 of this report shows that the CO model meets the NAAQS with this conservative operating
scenario. As such, modeling the diesel-fired emergency generator engine’s individual groupings was not
required.
5.2 Nearby CO Sources
No nearby sources of CO were required to be included as part of this model.5

5 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-1
6. NO2 MODELING ANALYSIS
The NO2 modeling analysis predicts ambient concentrations of NO2 due to emissions from the Facility. The
modeling output includes tabulated modeling results as compared to the NO2 1-hour and Annual NAAQS.
6.1 NO2 Special Processing
The majority of the emissions of NOX from air emission sources are in the form of nitric oxide (NO), whereas
EPA has established a NAAQS for NO2. EPA’s “Guideline on Air Quality Models” describes a three-tiered
screening approach to calculating NO2 concentrations based on dispersion model predictions of NOX
concentrations.

The three tiers, arranged in order from simplest to most refined, are:

• Tier 1 – Assume full conversion of NO to NO2, so that the NOX predicted by AERMOD is 100% NO2.
• Tier 2 – Ambient Ratio Method (ARM), where model predicted NOX concentrations are multiplied by a
NO2/NOX ambient ratio, derived from ambient monitoring data.
• Tier 3 – More detailed methods that account for the plume dispersion and chemistry may be considered
on a case-by-case basis, including the Ozone Limiting Method (OLM) and the Plume Volume Molar Ratio
Method (PVMRM).

For the NAAQS modeling of the Facility, a Tier 3 methodology utilizing OLM was used for the assessment of
NO2 impacts.
6.2 Background NO2 Concentrations
Background concentrations for NO2 for this modeling analysis were given by UDAQ from their Herriman
Monitoring station.6 The background data consists of design values calculated from data monitored from
2019-2021. The value used in the modeling analysis is the three-year average, high-third-high (H3H) of
seasonal 1-hour NO2 background. The background concentrations for NO2 are presented in Table 4-1 below.

6 Email from Dave Prey, UDAQ, March 08, 2024.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-2
Table 6-1. UDAQ-Provided NO2 Background Concentrations, H3H Seasonal 1-hour
Hour 3 Year Average (ppb)
Winter Spring Summer Fall
1.00 26.467 13.233 9.500 12.467
2.00 24.133 12.833 10.300 11.500
3.00 23.400 12.633 10.133 11.933
4.00 21.300 12.233 9.300 10.667
5.00 21.867 10.600 8.333 10.100
6.00 23.367 14.300 10.267 13.567
7.00 24.767 17.467 11.400 17.433
8.00 28.267 18.100 10.833 19.600
9.00 25.967 15.667 8.900 16.467
10.00 22.200 12.333 6.967 12.500
11.00 20.167 8.867 5.967 9.967
12.00 20.000 8.800 5.367 9.233
13.00 20.333 7.400 4.433 8.033
14.00 19.433 6.467 3.733 7.533
15.00 20.333 7.133 3.567 8.500
16.00 21.800 7.000 3.700 11.267
17.00 24.767 6.633 3.267 13.267
18.00 33.567 7.500 3.900 15.833
19.00 33.100 7.633 4.800 16.567
20.00 32.367 9.000 7.500 13.433
21.00 30.567 9.833 7.267 13.967
22.00 28.267 11.633 8.567 14.633
23.00 27.333 11.600 12.900 17.067
24.00 27.000 12.167 11.533 13.233
6.3 Background Ozone Concentrations
Background concentrations for ozone for this modeling analysis were given by UDAQ from their Herriman
Monitoring station.7 The background data consists of hourly ozone data that is concurrent with the
meteorological data provided by UDAQ in the form of an ozone background file. The background
concentrations for ozone will be included along with the modeling files delivered with this report.
6.4 Modeled NO2 Concentration
The resulting concentrations of 1-hour and annual NO2 from this air dispersion modeling analysis were
compared against the NO2 1-hour and annual NAAQS to demonstrate that emissions from the Facility do not
cause or contribute to an exceedance of the NO2 1-hour and annual NAAQS. The primary NAAQS is the
maximum concentration ceiling, measured in terms of total concentration of a pollutant in the atmosphere,
which is defined as the “level of air quality which the U.S. EPA judges are necessary, with an adequate
margin of safety, to protect the public health.”8 The 1-hour NO2 NAAQS requires the 8th highest
concentration over the five (5) modeled years to be compared to the standard. The annual NO2 NAAQS
requires that the 1st highest high concentration over the five (5) modeled years be compared to the

7 Email from Dave Prey, UDAQ, March 08, 2024. 8 40 CFR 50.2(b).

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-3
standard. The modeled concentration was added to the background concentrations for comparison to the
NAAQS. This calculation was completed based on results from the AERMOD modeling system.
6.5 NO2 NAAQS Analysis Results
A NAAQS analysis considers the impact from the sources at the Facility, nearby sources, and background
concentrations to yield a total concentration which is then compared to the NAAQS which, for 1-hour and 8-
hour NO2, is 188 and 100 µg/m3, respectively. Table 6-2 presents the model-predicted concentrations from
the Facility, nearby sources, and background concentrations according to the operating scenarios given in
Section 3.1.2, as well as comparisons to the 1-hour and annual NO2 NAAQS.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-4
Table 6-2. NO2 NAAQS Compliance Demonstration
Diesel-Fired
Emergency Generator Engines Operating Scenario1
Source Group2 Pollutant Averaging Period
Model-Predicted Concentration Including
Background (µg/m3)3
NAAQS (µg/m3) Percent of NAAQS
7 AM – 7 PM NOFF
NO2
1-hour 134.7 188 71.6%
Annual 42.1 100 42.1%
7 AM – 7 PM NS1G1 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS1G2 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS2G1 1-hour 130.5 188 69.4%
Annual 42.3 100 42.3%
7 AM – 7 PM NS2G2 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS3G1 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS3G2 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS4G1 1-hour 131.3 188 69.8%
Annual 42.4 100 42.4%
7 AM – 7 PM NS4G2 1-hour 130.5 188 69.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS5G1 1-hour 132.4 188 70.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS5G2 1-hour 134.2 188 71.4%
Annual 42.4 100 42.4%
7 AM – 7 PM NS6G1 1-hour 130.3 188 69.3%
Annual 42.5 100 42.5%
7 AM – 7 PM NS6G2 1-hour 147.7 188 78.6%
Annual 42.7 100 42.7%
7 AM – 7 PM NS7G1 1-hour 148.2 188 78.8%
Annual 42.7 100 42.7%
7 AM – 7 PM NS7G2 1-hour 149.0 188 79.3%
Annual 42.7 100 42.7%
7 AM – 7 PM NS8G1 1-hour 148.9 188 79.2%
Annual 42.7 100 42.7%
7 AM – 7 PM NS8G2 1-hour 145.2 188 77.2%
Annual 42.6 100 42.6%
7 AM – 7 PM NS10G1 1-hour 138.6 188 73.7%
Annual 42.5 100 42.5%
7 AM – 7 PM NS10G2 1-hour 135.9 188 72.3%
Annual 42.5 100 42.5%
1. All natural gas-fired generator engines and the boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario.
2. Each source group is incorporated within the corresponding air dispersion model files submitted with this report.
3. The 1-hour averaging period H8H is compared to the NAAQS. The annual averaging period H1H is compared to the NAAQS.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-5
In addition to this report, Novva is providing the AERMOD Input and Output files for UDAQ’s review. These
will be submitted separately.
6.6 NO2 Mitsubishi Method Analysis Results
For the 1-hour NO2 modeling, the “Mitsubishi Method” was employed to demonstrate compliance at on-
property receptors for the following nearby facilities, located to the east and south of the Facility:9

► PLBNEBAY;
► ORACLE;
► SME; and
► DANONE.
Specifically, for one nearby facility at a time, Novva’s data center and the other nearby facilities were
modeled to obtain total concentrations at receptors located on the property of the nearby facility in
question. For these models, the sources from the facility in question were turned off within the model (i.e.,
for this subset of receptors, a separate model was executed with all regional sources excluding the sources
from the nearby facility in question). This process was completed for each modeling scenario and source
group listed in Section 3.1.2 of this report. The maximum modeled concentrations excluding all nearby
facility’s on-site receptors are provided in Table 6-2. The maximum modeled concentrations including each
nearby facility’s on-site receptors are provided in Table 6-3 for reference.

9 U.S. EPA Memorandum from Robert D. Bauman (Chief SO2/Particulate Matter Programs Branch) to Gerald Fontenot (Chief Air Programs Branch, Region VI), Ambient Air, October 17, 1989.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 6-6
Table 6-3. Mitsubishi Method NO2 NAAQS Compliance Demonstration
Nearby
Source
Diesel-Fired Emergency Generator Engines
Operating Scenario1
Source
Group2 Pollutant Averaging
Period
Max Model-Predicted Concentration Including
Background (µg/m3)3
NAAQS
(µg/m3)
Percent of
NAAQS
Danone 7 AM – 7 PM NS7G2
NO2
1-hour 149.0 188 79.3%
7 AM – 7 PM NS8G1 Annual 42.7 100 42.7%
SME 7 AM – 7 PM NS7G2 1-hour 149.0 188 79.3%
7 AM – 7 PM NS8G1 Annual 42.7 100 42.7%
Oracle 7 AM – 7 PM NS7G2 1-hour 149.0 188 79.3%
7 AM – 7 PM NS8G1 Annual 42.7 100 42.7%
eBay 7 AM – 7 PM NS7G2 1-hour 149.0 188 79.3%
7 AM – 7 PM NS8G1 Annual 42.6 100 42.6%
1. All natural gas-fired generator engines and the boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario.
2. Each source group is incorporated within the corresponding air dispersion model files submitted with this report. 3. The 1-hour averaging period H8H is compared to the NAAQS. The annual averaging period H1H is compared to the NAAQS.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 7-1
7. PM10 MODELING ANALYSIS
The modeling analysis predicts ambient concentrations of PM10 due to emissions from the Facility. The
modeling output includes tabulated modeling results as compared to the PM10 24-hour NAAQS.
7.1 Background PM10 Concentrations
Background concentrations for PM10 for this modeling analysis were given by UDAQ from their Herriman
monitoring station.10 The background data consists of monthly tabulated maximums of 24-hour PM10 for the
years 2020-2022. The value used in the modeling analysis is the highest first high (H1H) monthly 24-hour
value, except for data outliers, as determined by UDAQ. The background concentrations used for the
modeling are presented in Table 7-1 below.
Table 7-1. UDAQ-Provided 24-hour PM10 Background Concentrations (µg/m3)
Year 2020 2021 2022 3 Year
Month Max Max Max Adj H2H
1 26 39 48 48
2 32 39 35 39
3 94 62 37 94
4 24 64 79 79
5 53 68 73 73
6 49 58 106 106
7 45 63 116 116
8 106 91 65 106
9 46 87 99 99
10 100 26 52 100
11 53 38 64 64
12 82 41 42 82
7.2 Modeled PM10 Concentration
The resulting concentration of PM10 from this air dispersion modeling analysis was compared against the
PM10 NAAQS to demonstrate that emissions from the Facility do not cause or contribute to an exceedance of
the PM10 NAAQS. The primary NAAQS is the maximum concentration ceiling, measured in terms of total
concentration of a pollutant in the atmosphere, which define the “level of air quality which the U.S. EPA
judges are necessary, with an adequate margin of safety, to protect the public health.”11 The 24-hour PM10
NAAQS requires the 6th highest concentration over the five (5) modeled years be compared to the standard.
The modeled concentration was added to the monthly background concentrations for comparison to the
NAAQS. This calculation was completed within the AERMOD modeling system.

10 Email from Dave Prey, UDAQ, March 08, 2024.
11 40 CFR 50.2(b).

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 7-2
7.3 PM10 NAAQS Analysis Results
A NAAQS analysis considers the impact from all sources at the Facility and background concentrations to
yield a total concentration which is then compared to the NAAQS which, for 24-hour PM10, is 150 µg/m3.
Table 7-2 presents the model-predicted concentrations from the Facility and background concentrations, as
well as a 24-hour PM10 NAAQS comparison.
Table 7-2. PM10 24-Hour NAAQS Compliance Demonstration
Diesel-Fired Emergency Generator Engines
Operating Scenario1
Pollutant Averaging
Period
Model-Predicted H6H
Concentration
(µg/m3)
NAAQS
(µg/m3)
Percent
of NAAQS
7 AM – 7 PM PM10 24-hour 137.1 150 91.4%
1. All natural gas-fired generator engines and the boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario.
In addition to this report, Novva is providing the AERMOD Input and Output files for UDAQ’s review. These
will be submitted separately.

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analyses Trinity Consultants 8-1
8. CO MODELING ANALYSIS
The modeling analysis predicts ambient concentrations of CO due to emissions from the Facility. The
modeling output includes tabulated modeling results as compared to the CO 1-hour and 8-hour NAAQS.
8.1 Background CO Concentrations
Background concentrations for CO for this modeling analysis were given by UDAQ from their Murray
monitoring station.12 The background data consists of one annual maximums of 1-hour CO. The background
concentrations used for the modeling are presented in Table 8-1 below.
Table 8-1. UDAQ-Provided 1-hour CO Background Concentrations
CO 1-hour Concentration (ppm)
1.9
8.2 Modeled CO Concentration
The resulting concentration of CO from this air dispersion modeling analysis was compared against the CO
NAAQS to demonstrate that emissions from the Facility do not cause or contribute to an exceedance of the
CO NAAQS. The primary NAAQS is the maximum concentration ceiling, measured in terms of total
concentration of a pollutant in the atmosphere, which define the “level of air quality which the U.S. EPA
judges are necessary, with an adequate margin of safety, to protect the public health.”13 The 1-hour and 8-
hour CO NAAQS requires the 1st highest concentration over the five (5) modeled years be compared to the
standard. The modeled concentration was added to the monthly background concentrations for comparison
to the NAAQS. This calculation was completed within the AERMOD modeling system.
8.3 CO NAAQS Analysis Results
A NAAQS analysis considers the impact from all sources at the Facility and background concentrations to
yield a total concentration which is then compared to the NAAQS which, for 1-hour and 8-hour CO, is
40,000 and 10,000 µg/m3, respectively. Table 8-2 presents the model-predicted concentrations from the
Facility and background concentrations, as well as 1-hour and 8-hour CO NAAQS comparisons.
Table 8-2. CO 1-hour & 8-Hour NAAQS Compliance Demonstration
Diesel-Fired Emergency Generator Engines Operating Scenario1 Pollutant Averaging
Period
Model-Predicted H1H Concentration (µg/m3)
NAAQS
(µg/m3)
Percent
of NAAQS
7 AM – 7 PM CO 1-hour 3,334 40,000 8.3%
8-hour 2,867 10,000 28.7%
1. All natural gas-fired generator engines and the boiler will operate 24 hours per day, 7 days a week, 52 weeks a year in each operating scenario.
In addition to this report, Novva is providing the AERMOD Input and Output files for UDAQ’s review. These
will be submitted separately.

12 Email from Dave Prey, UDAQ, March 08, 2024.
13 40 CFR 50.2(b).

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-1
APPENDIX A. WEST JORDAN FACILITY MODELING PARAMETERS AND EMISSION RATES
Table A-1. NO2 Uncapped Point Source Input Parameters
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN01 C2000 411449.0 4492171.4 1533.4 1.113449 12.80 751.48 42.37 0.46
GENN02 C2000 411448.9 4492167.4 1533.4 1.113449 12.80 751.48 42.37 0.46
GENN03 C2000 411448.8 4492164.0 1533.5 1.113449 12.80 751.48 42.37 0.46
GENN04 C2000 411448.6 4492160.5 1533.6 1.113449 12.80 751.48 42.37 0.46
GENN05 MTU1500
Miratech 411461.2 4492136.7 1533.8 0.922973 12.80 708.15 34.30 0.46
GENN06 MTU1500
Miratech 411460.8 4492127.9 1533.9 0.922973 12.80 708.15 34.30 0.46
GENN07 MTU1500 Miratech 411461.0 4492123.9 1534.0 0.922973 12.80 708.15 34.30 0.46
GENN08 MTU1500
Miratech 411460.8 4492119.2 1534.0 0.922973 12.80 708.15 34.30 0.46
GENN09 MTU1500
Miratech 411460.8 4492115.8 1534.1 0.922973 12.80 708.15 34.30 0.46
GENN10 MTU1500
Miratech 411460.6 4492106.7 1534.2 0.922973 12.80 708.15 34.30 0.46
GENN11 MTU1500
Miratech 411460.6 4492102.8 1534.2 0.922973 12.80 708.15 34.30 0.46
GENN12 MTU1500
Miratech 411460.5 4492093.5 1534.2 0.922973 12.80 708.15 34.30 0.46
GENN13 MTU1500 SafetyPower 411460.1 4492081.4 1534.3 1.048833 12.80 708.15 34.30 0.46
GENN14 MTU1750 411460.1 4492072.5 1534.4 1.065090 12.80 738.15 36.70 0.46
GENN15 MTU1750 411460.0 4492068.2 1534.4 1.065090 12.80 738.15 36.70 0.46
GENN16 MTU2000 411459.8 4492059.5 1534.4 1.075593 12.80 753.15 45.73 0.46
GENN17 MTU1500 Miratech 411460.0 4492050.1 1534.3 0.922973 12.80 708.15 34.30 0.46
GENN18 MTU1500
Miratech 411459.9 4492043.8 1534.4 0.922973 12.80 708.15 34.30 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-2
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN19 MTU1500 Miratech 411459.7 4492037.5 1534.5 0.922973 12.80 708.15 34.30 0.46
GENN20 MTU1500
Miratech 411459.6 4492030.4 1534.6 0.922973 12.80 708.15 34.30 0.46
GENN21 K2500 411459.5 4492020.2 1534.8 1.974000 12.80 773.15 58.07 0.46
GENN22 K2500 411459.4 4492014.3 1534.9 1.974000 12.80 773.15 58.07 0.46
GENN23 K2500 411459.4 4492009.3 1534.9 1.974000 12.80 773.15 58.07 0.46
GENN24 K2500 411459.3 4492004.6 1535.0 1.974000 12.80 773.15 58.07 0.46
GENN25 K2500 411459.2 4492000.0 1535.0 1.974000 12.80 773.15 58.07 0.46
GENN26 K2500 411459.0 4491989.3 1535.0 1.974000 12.80 773.15 58.07 0.46
GENN27 K2500 411458.7 4491976.7 1534.9 1.974000 12.80 773.15 58.07 0.46
GENN28 K2500 411458.7 4491969.3 1534.8 1.974000 12.80 773.15 58.07 0.46
GENN29 K2500 411458.6 4491962.5 1534.9 1.974000 12.80 773.15 58.07 0.46
GENN30 K2500 411458.5 4491955.4 1534.9 1.974000 12.80 773.15 58.07 0.46
GENN31 K2500 411458.3 4491948.2 1535.0 1.974000 12.80 773.15 58.07 0.46
GENN32 MTU2000 411458.0 4491931.1 1535.5 1.075593 12.80 753.15 45.73 0.46
GENN33 MTU1500
Miratech 411457.8 4491915.0 1535.8 0.922973 12.80 708.15 34.30 0.46
GENN34 MTU1500
Miratech 411457.6 4491905.8 1535.8 0.922973 12.80 708.15 34.30 0.46
GENN35 MTU1500
Miratech 411457.4 4491894.1 1535.7 0.922973 12.80 708.15 34.30 0.46
GENN36 MTU1500
Miratech 411457.2 4491884.1 1535.8 0.922973 12.80 708.15 34.30 0.46
OFFICE Office 411546.4 4492186.4 1530.7 0.581444 2.78 804.15 52.47 0.20
P3NP01 J620_SCR 411313.8 4491686.2 1541.6 0.018525 7.62 634.26 13.97 0.61
P3NP02 J620_SCR 411319.5 4491686.1 1541.4 0.018525 7.62 634.26 13.97 0.61
P3NP03 J620_SCR 411325.1 4491686.1 1541.3 0.018525 7.62 634.26 13.97 0.61
P3NP04 J620_SCR 411330.6 4491686.1 1541.2 0.018525 7.62 634.26 13.97 0.61
P3NP05 J620_SCR 411336.2 4491686.0 1541.0 0.018525 7.62 634.26 13.97 0.61
P3NP06 J620_SCR 411341.6 4491686.0 1540.9 0.018525 7.62 634.26 13.97 0.61
P3NP07 J620_SCR 411347.1 4491686.0 1540.7 0.018525 7.62 634.26 13.97 0.61
P3NP08 J620_SCR 411352.9 4491685.9 1540.6 0.018525 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-3
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P3NP09 J620_SCR 411358.4 4491685.9 1540.5 0.018525 7.62 634.26 13.97 0.61
P3NP10 J620_SCR 411374.6 4491685.8 1540.0 0.018525 7.62 634.26 13.97 0.61
P3NP11 J620_SCR 411380.2 4491685.8 1539.9 0.018525 7.62 634.26 13.97 0.61
P3NP12 J620_SCR 411385.8 4491685.8 1539.7 0.018525 7.62 634.26 13.97 0.61
P3NP13 J620_SCR 411391.3 4491685.7 1539.6 0.018525 7.62 634.26 13.97 0.61
P3NP14 J620_SCR 411396.9 4491685.7 1539.4 0.018525 7.62 634.26 13.97 0.61
P3NP15 J620_SCR 411402.4 4491685.7 1539.3 0.018525 7.62 634.26 13.97 0.61
P3NP16 J620_SCR 411407.9 4491685.6 1539.1 0.018525 7.62 634.26 13.97 0.61
P3NP17 J620_SCR 411413.6 4491685.6 1538.9 0.018525 7.62 634.26 13.97 0.61
P3NP18 J620_SCR 411419.1 4491685.6 1538.7 0.018525 7.62 634.26 13.97 0.61
P2NP01 J620_SCR 411313.6 4491633.3 1542.7 0.018525 7.62 634.26 13.97 0.61
P2NP02 J620_SCR 411319.3 4491633.3 1542.5 0.018525 7.62 634.26 13.97 0.61
P2NP03 J620_SCR 411324.8 4491633.2 1542.4 0.018525 7.62 634.26 13.97 0.61
P2NP04 J620_SCR 411330.3 4491633.1 1542.3 0.018525 7.62 634.26 13.97 0.61
P2NP05 J620_SCR 411335.9 4491633.2 1542.1 0.018525 7.62 634.26 13.97 0.61
P2NP06 J620_SCR 411341.4 4491633.1 1542.0 0.018525 7.62 634.26 13.97 0.61
P2NP07 J620_SCR 411347.0 4491633.1 1541.9 0.018525 7.62 634.26 13.97 0.61
P2NP08 J620_SCR 411352.6 4491633.0 1541.7 0.018525 7.62 634.26 13.97 0.61
P2NP09 J620_SCR 411358.2 4491633.0 1541.6 0.018525 7.62 634.26 13.97 0.61
P2NP10 J620_SCR 411374.3 4491632.9 1541.1 0.018525 7.62 634.26 13.97 0.61
P2NP11 J620_SCR 411379.8 4491632.9 1540.9 0.018525 7.62 634.26 13.97 0.61
P2NP12 J620_SCR 411385.4 4491632.8 1540.7 0.018525 7.62 634.26 13.97 0.61
P2NP13 J620_SCR 411390.9 4491632.8 1540.4 0.018525 7.62 634.26 13.97 0.61
P2NP14 J620_SCR 411396.5 4491632.8 1540.2 0.018525 7.62 634.26 13.97 0.61
P2NP15 J620_SCR 411402.1 4491632.7 1540.0 0.018525 7.62 634.26 13.97 0.61
P2NP16 J620_SCR 411407.5 4491632.7 1539.8 0.018525 7.62 634.26 13.97 0.61
P2NP17 J620_SCR 411413.3 4491632.7 1539.6 0.018525 7.62 634.26 13.97 0.61
P2NP18 J620_SCR 411418.7 4491632.6 1539.4 0.018525 7.62 634.26 13.97 0.61
P4NP01 J620_SCR 411313.2 4491580.8 1543.1 0.018525 7.62 634.26 13.97 0.61
P4NP02 J620_SCR 411318.9 4491580.7 1542.9 0.018525 7.62 634.26 13.97 0.61
P4NP03 J620_SCR 411324.5 4491580.7 1542.7 0.018525 7.62 634.26 13.97 0.61
P4NP04 J620_SCR 411330.0 4491580.7 1542.6 0.018525 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-4
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P4NP05 J620_SCR 411335.6 4491580.6 1542.5 0.018525 7.62 634.26 13.97 0.61
P4NP06 J620_SCR 411341.0 4491580.6 1542.3 0.018525 7.62 634.26 13.97 0.61
P4NP07 J620_SCR 411346.5 4491580.6 1542.2 0.018525 7.62 634.26 13.97 0.61
P4NP08 J620_SCR 411352.3 4491580.5 1542.1 0.018525 7.62 634.26 13.97 0.61
P4NP09 J620_SCR 411357.8 4491580.5 1542.0 0.018525 7.62 634.26 13.97 0.61
P4NP10 J620_SCR 411374.0 4491580.4 1541.6 0.018525 7.62 634.26 13.97 0.61
P4NP11 J620_SCR 411379.6 4491580.4 1541.5 0.018525 7.62 634.26 13.97 0.61
P4NP12 J620_SCR 411385.2 4491580.4 1541.4 0.018525 7.62 634.26 13.97 0.61
P4NP13 J620_SCR 411390.7 4491580.3 1541.2 0.018525 7.62 634.26 13.97 0.61
P4NP14 J620_SCR 411396.3 4491580.3 1541.1 0.018525 7.62 634.26 13.97 0.61
P4NP15 J620_SCR 411401.8 4491580.3 1540.9 0.018525 7.62 634.26 13.97 0.61
P4NP16 J620_SCR 411407.3 4491580.2 1540.7 0.018525 7.62 634.26 13.97 0.61
P4NP17 J620_SCR 411413.0 4491580.2 1540.5 0.018525 7.62 634.26 13.97 0.61
P4NP18 J620_SCR 411418.5 4491580.2 1540.3 0.018525 7.62 634.26 13.97 0.61
P5NP01 J620_SCR 411313.0 4491527.9 1543.3 0.018525 7.62 634.26 13.97 0.61
P5NP02 J620_SCR 411318.7 4491527.9 1543.1 0.018525 7.62 634.26 13.97 0.61
P5NP03 J620_SCR 411324.2 4491527.8 1543.0 0.018525 7.62 634.26 13.97 0.61
P5NP04 J620_SCR 411329.7 4491527.7 1542.9 0.018525 7.62 634.26 13.97 0.61
P5NP05 J620_SCR 411335.3 4491527.8 1542.8 0.018525 7.62 634.26 13.97 0.61
P5NP06 J620_SCR 411340.8 4491527.7 1542.7 0.018525 7.62 634.26 13.97 0.61
P5NP07 J620_SCR 411346.4 4491527.7 1542.6 0.018525 7.62 634.26 13.97 0.61
P5NP08 J620_SCR 411352.0 4491527.6 1542.5 0.018525 7.62 634.26 13.97 0.61
P5NP09 J620_SCR 411357.6 4491527.6 1542.3 0.018525 7.62 634.26 13.97 0.61
P5NP10 J620_SCR 411373.7 4491527.5 1542.0 0.018525 7.62 634.26 13.97 0.61
P5NP11 J620_SCR 411379.2 4491527.5 1541.9 0.018525 7.62 634.26 13.97 0.61
P5NP12 J620_SCR 411384.8 4491527.4 1541.7 0.018525 7.62 634.26 13.97 0.61
P5NP13 J620_SCR 411390.3 4491527.4 1541.6 0.018525 7.62 634.26 13.97 0.61
P5NP14 J620_SCR 411395.9 4491527.4 1541.5 0.018525 7.62 634.26 13.97 0.61
P5NP15 J620_SCR 411401.5 4491527.3 1541.4 0.018525 7.62 634.26 13.97 0.61
P5NP16 J620_SCR 411406.9 4491527.3 1541.2 0.018525 7.62 634.26 13.97 0.61
P5NP17 J620_SCR 411412.7 4491527.3 1541.1 0.018525 7.62 634.26 13.97 0.61
P5NP18 J620_SCR 411418.1 4491527.2 1540.9 0.018525 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-5
Table A-2. NO2 Capped Point Source Input Parameters
ID Description X Coordinate (m)
Y Coordinate (m)
Elevatio
n (m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
BOIL1 Hot Water Boiler 411519.2 4492181.3 1531.66 0.024705 2.44 435.93 7.45 0.15
Table A-3. NO2 Nearby Uncapped Point Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevation (m) Emission Rate (g/s)
Stack Height
(m)
Stack Temp.
(K)
Stack Velocity
(m/s)
Stack Diameter
(m)
SLC1_G02 eBay 411283.5 4490966.2 1546.50 1.826368 5.71 668.13 16.56 0.71
SLC1_G03 eBay 411295.4 4490966.2 1546.75 1.826368 5.71 668.13 16.56 0.71
SLC1_G04 eBay 411307.8 4490966.2 1546.99 1.826368 5.71 668.13 16.56 0.71
SLC1_G05 eBay 411319.4 4490966.2 1547.25 1.826368 5.71 668.13 16.56 0.71
SLC2_G14 eBay 411383.5 4490828.0 1545.61 6.853707 6.71 735.43 33.70 0.61
HEATEXCH Danone 412215.9 4492747.5 1506.58 0.774887 13.59 394.26 5.02 1.52
BOILER4 Danone 412212.9 4492725.0 1506.79 0.042839 14.33 478.15 11.71 0.81
SLC3_G30 eBay 411130.4 4490957.3 1550.73 1.216438 8.23 614.18 19.14 0.46
SLC3_G32 eBay 411130.8 4490944.0 1550.75 0.662975 3.84 706.19 7.42 0.46
STCK1 Oracle 412204.1 4491301.5 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK2 Oracle 412204.4 4491308.4 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK3 Oracle 412204.8 4491314.4 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK4 Oracle 412205.8 4491320.9 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK5 Oracle 412207.4 4491334.0 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK6 Oracle 412208.2 4491340.5 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK7 Oracle 412208.5 4491346.5 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK8 Oracle 412209.6 4491353.2 1516.69 0.756391 4.88 763.15 51.21 0.46
STCK9 Oracle 412201.5 4491257.3 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK10 Oracle 412200.4 4491250.9 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK11 Oracle 412195.5 4491241.0 1516.69 0.851785 5.14 713.71 107.48 0.36
STCK12 Oracle 412206.1 4491205.0 1516.69 0.220709 4.08 708.71 90.92 0.20
STCK1NL Oracle 412204.1 4491301.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK2NL Oracle 412204.4 4491308.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK3NL Oracle 412204.8 4491314.4 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK4NL Oracle 412205.8 4491320.9 1516.69 0.756390 4.88 763.15 51.21 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-6
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
STCK5NL Oracle 412207.4 4491334.0 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK6NL Oracle 412208.2 4491340.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK7NL Oracle 412208.5 4491346.5 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK8NL Oracle 412209.6 4491353.2 1516.69 0.756390 4.88 763.15 51.21 0.46
STCK9NL Oracle 412201.5 4491257.3 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK10NL Oracle 412200.4 4491250.9 1516.69 0.846706 6.50 729.26 96.10 0.36
STCK11NL Oracle 412195.5 4491241.0 1516.69 0.851785 5.14 713.71 107.48 0.36
STCK12NL Oracle 412206.1 4491205.0 1516.69 0.220709 4.08 708.71 90.92 0.20
GEN SME 412943.3 4492242.3 1497.23 1.348177 3.66 773.15 12.94 0.18
PLASMA96 SME 412698.0 4492190.0 1505.37 0.109996 3.25 294.26 2.93 1.14
PLASMA60 SME 412698.0 4492180.0 1505.38 0.109996 3.72 294.26 4.41 1.14
FICEP SME 412585.0 4491991.0 1504.60 0.109996 3.25 294.26 2.93 1.14
ROBOT SME 412657.0 4492214.0 1505.17 0.109996 2.55 294.26 4.60 1.14
PLASMA20 SME 412679.0 4492107.0 1505.45 0.000000 3.37 294.26 3.67 1.14
OA_FPUMP Oracle 412202.8 4491280.7 1516.69 0.120743 3.05 764.00 45.44 0.06
Table A-4 NO2 Nearby Volume Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevation (m) Emission Rate (g/s) Release Height (m) Init. lat. dim. (m) Init. vert. dim. (m)
WELDING SME 412651.0 4492163.0 1505.43 0.000000 5.00 23.25 4.65
Table A-5. PM10 Uncapped Point Source Input Parameters
ID Description
X
Coordinate (m)
Y
Coordinate (m)
Elevation (m) Emission Rate (g/s)
Stack
Height (m)
Stack
Temp. (K)
Stack
Velocity (m/s)
Stack
Diameter (m)
GENN01 C2000 411449.0 4492171.4 1533.36 0.032468 12.80 751.48 42.37 0.46
GENN02 C2000 411448.9 4492167.4 1533.44 0.032468 12.80 751.48 42.37 0.46
GENN03 C2000 411448.8 4492164.0 1533.51 0.032468 12.80 751.48 42.37 0.46
GENN04 C2000 411448.6 4492160.5 1533.59 0.032468 12.80 751.48 42.37 0.46
GENN05 MTU1500
Miratech
411461.2 4492136.7 1533.82 0.033756 12.80 708.15 34.30 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-7
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN06 MTU1500 Miratech 411460.8 4492127.9 1533.94 0.033756 12.80 708.15 34.30 0.46
GENN07 MTU1500
Miratech
411461.0 4492123.9 1533.98 0.033756 12.80 708.15 34.30 0.46
GENN08 MTU1500
Miratech
411460.8 4492119.2 1534.04 0.033756 12.80 708.15 34.30 0.46
GENN09 MTU1500
Miratech
411460.8 4492115.8 1534.07 0.033756 12.80 708.15 34.30 0.46
GENN10 MTU1500
Miratech
411460.6 4492106.7 1534.15 0.033756 12.80 708.15 34.30 0.46
GENN11 MTU1500
Miratech
411460.6 4492102.8 1534.17 0.033756 12.80 708.15 34.30 0.46
GENN12 MTU1500 Miratech 411460.5 4492093.5 1534.24 0.033756 12.80 708.15 34.30 0.46
GENN13 MTU1500
SafetyPower
411460.1 4492081.4 1534.31 0.033756 12.80 708.15 34.30 0.46
GENN14 MTU1750 411460.1 4492072.5 1534.35 0.038200 12.80 738.15 36.70 0.46
GENN15 MTU1750 411460.0 4492068.2 1534.36 0.038200 12.80 738.15 36.70 0.46
GENN16 MTU2000 411459.8 4492059.5 1534.37 0.073434 12.80 753.15 45.73 0.46
GENN17 MTU1500
Miratech
411460.0 4492050.1 1534.34 0.033756 12.80 708.15 34.30 0.46
GENN18 MTU1500
Miratech
411459.9 4492043.8 1534.40 0.033756 12.80 708.15 34.30 0.46
GENN19 MTU1500
Miratech
411459.7 4492037.5 1534.49 0.033756 12.80 708.15 34.30 0.46
GENN20 MTU1500
Miratech
411459.6 4492030.4 1534.64 0.033756 12.80 708.15 34.30 0.46
GENN21 K2500 411459.5 4492020.2 1534.79 0.075000 12.80 773.15 58.07 0.46
GENN22 K2500 411459.4 4492014.3 1534.87 0.075000 12.80 773.15 58.07 0.46
GENN23 K2500 411459.4 4492009.3 1534.92 0.075000 12.80 773.15 58.07 0.46
GENN24 K2500 411459.3 4492004.6 1534.97 0.075000 12.80 773.15 58.07 0.46
GENN25 K2500 411459.2 4492000.0 1535.01 0.075000 12.80 773.15 58.07 0.46
GENN26 K2500 411459.0 4491989.3 1534.97 0.075000 12.80 773.15 58.07 0.46
GENN27 K2500 411458.7 4491976.7 1534.87 0.075000 12.80 773.15 58.07 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-8
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN28 K2500 411458.7 4491969.3 1534.83 0.075000 12.80 773.15 58.07 0.46
GENN29 K2500 411458.6 4491962.5 1534.85 0.075000 12.80 773.15 58.07 0.46
GENN30 K2500 411458.5 4491955.4 1534.92 0.075000 12.80 773.15 58.07 0.46
GENN31 K2500 411458.3 4491948.2 1535.02 0.075000 12.80 773.15 58.07 0.46
GENN32 MTU2000 411458.0 4491931.1 1535.46 0.073434 12.80 753.15 45.73 0.46
GENN33 MTU1500
Miratech
411457.8 4491915.0 1535.78 0.033756 12.80 708.15 34.30 0.46
GENN34 MTU1500
Miratech
411457.6 4491905.8 1535.75 0.033756 12.80 708.15 34.30 0.46
GENN35 MTU1500
Miratech
411457.4 4491894.1 1535.72 0.033756 12.80 708.15 34.30 0.46
GENN36 MTU1500
Miratech
411457.2 4491884.1 1535.75 0.033756 12.80 708.15 34.30 0.46
OFFICE Office 411546.4 4492186.4 1530.74 0.005885 2.78 804.15 52.47 0.20
P3NP01 J620_SCR 411313.8 4491686.2 1541.57 0.012188 7.62 634.26 13.97 0.61
P3NP02 J620_SCR 411319.5 4491686.1 1541.44 0.012188 7.62 634.26 13.97 0.61
P3NP03 J620_SCR 411325.1 4491686.1 1541.31 0.012188 7.62 634.26 13.97 0.61
P3NP04 J620_SCR 411330.6 4491686.1 1541.16 0.012188 7.62 634.26 13.97 0.61
P3NP05 J620_SCR 411336.2 4491686.0 1541.02 0.012188 7.62 634.26 13.97 0.61
P3NP06 J620_SCR 411341.6 4491686.0 1540.88 0.012188 7.62 634.26 13.97 0.61
P3NP07 J620_SCR 411347.1 4491686.0 1540.74 0.012188 7.62 634.26 13.97 0.61
P3NP08 J620_SCR 411352.9 4491685.9 1540.60 0.012188 7.62 634.26 13.97 0.61
P3NP09 J620_SCR 411358.4 4491685.9 1540.47 0.012188 7.62 634.26 13.97 0.61
P3NP10 J620_SCR 411374.6 4491685.8 1540.03 0.012188 7.62 634.26 13.97 0.61
P3NP11 J620_SCR 411380.2 4491685.8 1539.88 0.012188 7.62 634.26 13.97 0.61
P3NP12 J620_SCR 411385.8 4491685.8 1539.74 0.012188 7.62 634.26 13.97 0.61
P3NP13 J620_SCR 411391.3 4491685.7 1539.58 0.012188 7.62 634.26 13.97 0.61
P3NP14 J620_SCR 411396.9 4491685.7 1539.43 0.012188 7.62 634.26 13.97 0.61
P3NP15 J620_SCR 411402.4 4491685.7 1539.28 0.012188 7.62 634.26 13.97 0.61
P3NP16 J620_SCR 411407.9 4491685.6 1539.13 0.012188 7.62 634.26 13.97 0.61
P3NP17 J620_SCR 411413.6 4491685.6 1538.94 0.012188 7.62 634.26 13.97 0.61
P3NP18 J620_SCR 411419.1 4491685.6 1538.73 0.012188 7.62 634.26 13.97 0.61
P2NP01 J620_SCR 411313.6 4491633.3 1542.67 0.012188 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-9
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P2NP02 J620_SCR 411319.3 4491633.3 1542.54 0.012188 7.62 634.26 13.97 0.61
P2NP03 J620_SCR 411324.8 4491633.2 1542.41 0.012188 7.62 634.26 13.97 0.61
P2NP04 J620_SCR 411330.3 4491633.1 1542.27 0.012188 7.62 634.26 13.97 0.61
P2NP05 J620_SCR 411335.9 4491633.2 1542.13 0.012188 7.62 634.26 13.97 0.61
P2NP06 J620_SCR 411341.4 4491633.1 1542.00 0.012188 7.62 634.26 13.97 0.61
P2NP07 J620_SCR 411347.0 4491633.1 1541.87 0.012188 7.62 634.26 13.97 0.61
P2NP08 J620_SCR 411352.6 4491633.0 1541.73 0.012188 7.62 634.26 13.97 0.61
P2NP09 J620_SCR 411358.2 4491633.0 1541.58 0.012188 7.62 634.26 13.97 0.61
P2NP10 J620_SCR 411374.3 4491632.9 1541.06 0.012188 7.62 634.26 13.97 0.61
P2NP11 J620_SCR 411379.8 4491632.9 1540.86 0.012188 7.62 634.26 13.97 0.61
P2NP12 J620_SCR 411385.4 4491632.8 1540.66 0.012188 7.62 634.26 13.97 0.61
P2NP13 J620_SCR 411390.9 4491632.8 1540.44 0.012188 7.62 634.26 13.97 0.61
P2NP14 J620_SCR 411396.5 4491632.8 1540.22 0.012188 7.62 634.26 13.97 0.61
P2NP15 J620_SCR 411402.1 4491632.7 1540.00 0.012188 7.62 634.26 13.97 0.61
P2NP16 J620_SCR 411407.5 4491632.7 1539.79 0.012188 7.62 634.26 13.97 0.61
P2NP17 J620_SCR 411413.3 4491632.7 1539.56 0.012188 7.62 634.26 13.97 0.61
P2NP18 J620_SCR 411418.7 4491632.6 1539.36 0.012188 7.62 634.26 13.97 0.61
P4NP01 J620_SCR 411313.2 4491580.8 1543.07 0.012188 7.62 634.26 13.97 0.61
P4NP02 J620_SCR 411318.9 4491580.7 1542.90 0.012188 7.62 634.26 13.97 0.61
P4NP03 J620_SCR 411324.5 4491580.7 1542.74 0.012188 7.62 634.26 13.97 0.61
P4NP04 J620_SCR 411330.0 4491580.7 1542.59 0.012188 7.62 634.26 13.97 0.61
P4NP05 J620_SCR 411335.6 4491580.6 1542.45 0.012188 7.62 634.26 13.97 0.61
P4NP06 J620_SCR 411341.0 4491580.6 1542.33 0.012188 7.62 634.26 13.97 0.61
P4NP07 J620_SCR 411346.5 4491580.6 1542.22 0.012188 7.62 634.26 13.97 0.61
P4NP08 J620_SCR 411352.3 4491580.5 1542.10 0.012188 7.62 634.26 13.97 0.61
P4NP09 J620_SCR 411357.8 4491580.5 1541.98 0.012188 7.62 634.26 13.97 0.61
P4NP10 J620_SCR 411374.0 4491580.4 1541.60 0.012188 7.62 634.26 13.97 0.61
P4NP11 J620_SCR 411379.6 4491580.4 1541.48 0.012188 7.62 634.26 13.97 0.61
P4NP12 J620_SCR 411385.2 4491580.4 1541.36 0.012188 7.62 634.26 13.97 0.61
P4NP13 J620_SCR 411390.7 4491580.3 1541.23 0.012188 7.62 634.26 13.97 0.61
P4NP14 J620_SCR 411396.3 4491580.3 1541.08 0.012188 7.62 634.26 13.97 0.61
P4NP15 J620_SCR 411401.8 4491580.3 1540.91 0.012188 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-10
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P4NP16 J620_SCR 411407.3 4491580.2 1540.72 0.012188 7.62 634.26 13.97 0.61
P4NP17 J620_SCR 411413.0 4491580.2 1540.51 0.012188 7.62 634.26 13.97 0.61
P4NP18 J620_SCR 411418.5 4491580.2 1540.29 0.012188 7.62 634.26 13.97 0.61
P5NP01 J620_SCR 411313.0 4491527.9 1543.27 0.012188 7.62 634.26 13.97 0.61
P5NP02 J620_SCR 411318.7 4491527.9 1543.12 0.012188 7.62 634.26 13.97 0.61
P5NP03 J620_SCR 411324.2 4491527.8 1542.99 0.012188 7.62 634.26 13.97 0.61
P5NP04 J620_SCR 411329.7 4491527.7 1542.87 0.012188 7.62 634.26 13.97 0.61
P5NP05 J620_SCR 411335.3 4491527.8 1542.75 0.012188 7.62 634.26 13.97 0.61
P5NP06 J620_SCR 411340.8 4491527.7 1542.65 0.012188 7.62 634.26 13.97 0.61
P5NP07 J620_SCR 411346.4 4491527.7 1542.55 0.012188 7.62 634.26 13.97 0.61
P5NP08 J620_SCR 411352.0 4491527.6 1542.45 0.012188 7.62 634.26 13.97 0.61
P5NP09 J620_SCR 411357.6 4491527.6 1542.34 0.012188 7.62 634.26 13.97 0.61
P5NP10 J620_SCR 411373.7 4491527.5 1541.98 0.012188 7.62 634.26 13.97 0.61
P5NP11 J620_SCR 411379.2 4491527.5 1541.85 0.012188 7.62 634.26 13.97 0.61
P5NP12 J620_SCR 411384.8 4491527.4 1541.72 0.012188 7.62 634.26 13.97 0.61
P5NP13 J620_SCR 411390.3 4491527.4 1541.59 0.012188 7.62 634.26 13.97 0.61
P5NP14 J620_SCR 411395.9 4491527.4 1541.47 0.012188 7.62 634.26 13.97 0.61
P5NP15 J620_SCR 411401.5 4491527.3 1541.36 0.012188 7.62 634.26 13.97 0.61
P5NP16 J620_SCR 411406.9 4491527.3 1541.24 0.012188 7.62 634.26 13.97 0.61
P5NP17 J620_SCR 411412.7 4491527.3 1541.08 0.012188 7.62 634.26 13.97 0.61
P5NP18 J620_SCR 411418.1 4491527.2 1540.93 0.012188 7.62 634.26 13.97 0.61
Table A-6. PM10 Capped Point Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevation (m) Emission Rate (g/s)
Stack Height
(m)
Stack Temp.
(K)
Stack Velocity
(m/s)
Stack Diameter
(m)
BOIL1 Hot Water Boiler 411519.2 4492181.3 1531.66 0.001878 2.44 435.93 7.45 0.15
Table A-7. CO Uncapped Point Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevation (m) Emission Rate (g/s)
Stack Height
(m)
Stack Temp.
(K)
Stack Velocity
(m/s)
Stack Diameter
(m)
GENN01 C2000 411449.0 4492171.4 1533.36 0.195929 12.80 751.48 42.37 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-11
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN02 C2000 411448.9 4492167.4 1533.44 0.195929 12.80 751.48 42.37 0.46
GENN03 C2000 411448.8 4492164.0 1533.51 0.195929 12.80 751.48 42.37 0.46
GENN04 C2000 411448.6 4492160.5 1533.59 0.195929 12.80 751.48 42.37 0.46
GENN05 MTU1500 Miratech 411461.2 4492136.7 1533.82 0.530444 12.80 708.15 34.30 0.46
GENN06 MTU1500
Miratech
411460.8 4492127.9 1533.94 0.530444 12.80 708.15 34.30 0.46
GENN07 MTU1500
Miratech
411461.0 4492123.9 1533.98 0.530444 12.80 708.15 34.30 0.46
GENN08 MTU1500
Miratech
411460.8 4492119.2 1534.04 0.530444 12.80 708.15 34.30 0.46
GENN09 MTU1500
Miratech
411460.8 4492115.8 1534.07 0.530444 12.80 708.15 34.30 0.46
GENN10 MTU1500
Miratech
411460.6 4492106.7 1534.15 0.530444 12.80 708.15 34.30 0.46
GENN11 MTU1500 Miratech 411460.6 4492102.8 1534.17 0.530444 12.80 708.15 34.30 0.46
GENN12 MTU1500
Miratech
411460.5 4492093.5 1534.24 0.530444 12.80 708.15 34.30 0.46
GENN13 MTU1500
SafetyPower
411460.1 4492081.4 1534.31 0.530444 12.80 708.15 34.30 0.46
GENN14 MTU1750 411460.1 4492072.5 1534.35 0.695028 12.80 738.15 36.70 0.46
GENN15 MTU1750 411460.0 4492068.2 1534.36 0.695028 12.80 738.15 36.70 0.46
GENN16 MTU2000 411459.8 4492059.5 1534.37 1.202806 12.80 753.15 45.73 0.46
GENN17 MTU1500
Miratech
411460.0 4492050.1 1534.34 0.530444 12.80 708.15 34.30 0.46
GENN18 MTU1500
Miratech
411459.9 4492043.8 1534.4 0.530444 12.80 708.15 34.30 0.46
GENN19 MTU1500
Miratech
411459.7 4492037.5 1534.49 0.530444 12.80 708.15 34.30 0.46
GENN20 MTU1500 Miratech 411459.6 4492030.4 1534.64 0.530444 12.80 708.15 34.30 0.46
GENN21 K2500 411459.5 4492020.2 1534.79 0.750000 12.80 773.15 58.07 0.46
GENN22 K2500 411459.4 4492014.3 1534.87 0.750000 12.80 773.15 58.07 0.46

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-12
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
GENN23 K2500 411459.4 4492009.3 1534.92 0.750000 12.80 773.15 58.07 0.46
GENN24 K2500 411459.3 4492004.6 1534.97 0.750000 12.80 773.15 58.07 0.46
GENN25 K2500 411459.2 4492000.0 1535.01 0.750000 12.80 773.15 58.07 0.46
GENN26 K2500 411459.0 4491989.3 1534.97 0.750000 12.80 773.15 58.07 0.46
GENN27 K2500 411458.7 4491976.7 1534.87 0.750000 12.80 773.15 58.07 0.46
GENN28 K2500 411458.7 4491969.3 1534.83 0.750000 12.80 773.15 58.07 0.46
GENN29 K2500 411458.6 4491962.5 1534.85 0.750000 12.80 773.15 58.07 0.46
GENN30 K2500 411458.5 4491955.4 1534.92 0.750000 12.80 773.15 58.07 0.46
GENN31 K2500 411458.3 4491948.2 1535.02 0.750000 12.80 773.15 58.07 0.46
GENN32 MTU2000 411458.0 4491931.1 1535.46 1.202806 12.80 753.15 45.73 0.46
GENN33 MTU1500 Miratech 411457.8 4491915.0 1535.78 0.530444 12.80 708.15 34.30 0.46
GENN34 MTU1500
Miratech
411457.6 4491905.8 1535.75 0.530444 12.80 708.15 34.30 0.46
GENN35 MTU1500
Miratech
411457.4 4491894.1 1535.72 0.530444 12.80 708.15 34.30 0.46
GENN36 MTU1500
Miratech
411457.2 4491884.1 1535.75 0.530444 12.80 708.15 34.30 0.46
OFFICE Office 411546.4 4492186.4 1530.74 0.137710 2.78 804.15 52.47 0.20
P3NP01 J620_SCR 411313.8 4491686.2 1541.57 0.079220 7.62 634.26 13.97 0.61
P3NP02 J620_SCR 411319.5 4491686.1 1541.44 0.079220 7.62 634.26 13.97 0.61
P3NP03 J620_SCR 411325.1 4491686.1 1541.31 0.079220 7.62 634.26 13.97 0.61
P3NP04 J620_SCR 411330.6 4491686.1 1541.16 0.079220 7.62 634.26 13.97 0.61
P3NP05 J620_SCR 411336.2 4491686.0 1541.02 0.079220 7.62 634.26 13.97 0.61
P3NP06 J620_SCR 411341.6 4491686.0 1540.88 0.079220 7.62 634.26 13.97 0.61
P3NP07 J620_SCR 411347.1 4491686.0 1540.74 0.079220 7.62 634.26 13.97 0.61
P3NP08 J620_SCR 411352.9 4491685.9 1540.6 0.079220 7.62 634.26 13.97 0.61
P3NP09 J620_SCR 411358.4 4491685.9 1540.47 0.079220 7.62 634.26 13.97 0.61
P3NP10 J620_SCR 411374.6 4491685.8 1540.03 0.079220 7.62 634.26 13.97 0.61
P3NP11 J620_SCR 411380.2 4491685.8 1539.88 0.079220 7.62 634.26 13.97 0.61
P3NP12 J620_SCR 411385.8 4491685.8 1539.74 0.079220 7.62 634.26 13.97 0.61
P3NP13 J620_SCR 411391.3 4491685.7 1539.58 0.079220 7.62 634.26 13.97 0.61
P3NP14 J620_SCR 411396.9 4491685.7 1539.43 0.079220 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-13
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P3NP15 J620_SCR 411402.4 4491685.7 1539.28 0.079220 7.62 634.26 13.97 0.61
P3NP16 J620_SCR 411407.9 4491685.6 1539.13 0.079220 7.62 634.26 13.97 0.61
P3NP17 J620_SCR 411413.6 4491685.6 1538.94 0.079220 7.62 634.26 13.97 0.61
P3NP18 J620_SCR 411419.1 4491685.6 1538.73 0.079220 7.62 634.26 13.97 0.61
P2NP01 J620_SCR 411313.6 4491633.3 1542.67 0.079220 7.62 634.26 13.97 0.61
P2NP02 J620_SCR 411319.3 4491633.3 1542.54 0.079220 7.62 634.26 13.97 0.61
P2NP03 J620_SCR 411324.8 4491633.2 1542.41 0.079220 7.62 634.26 13.97 0.61
P2NP04 J620_SCR 411330.3 4491633.1 1542.27 0.079220 7.62 634.26 13.97 0.61
P2NP05 J620_SCR 411335.9 4491633.2 1542.13 0.079220 7.62 634.26 13.97 0.61
P2NP06 J620_SCR 411341.4 4491633.1 1542 0.079220 7.62 634.26 13.97 0.61
P2NP07 J620_SCR 411347.0 4491633.1 1541.87 0.079220 7.62 634.26 13.97 0.61
P2NP08 J620_SCR 411352.6 4491633.0 1541.73 0.079220 7.62 634.26 13.97 0.61
P2NP09 J620_SCR 411358.2 4491633.0 1541.58 0.079220 7.62 634.26 13.97 0.61
P2NP10 J620_SCR 411374.3 4491632.9 1541.06 0.079220 7.62 634.26 13.97 0.61
P2NP11 J620_SCR 411379.8 4491632.9 1540.86 0.079220 7.62 634.26 13.97 0.61
P2NP12 J620_SCR 411385.4 4491632.8 1540.66 0.079220 7.62 634.26 13.97 0.61
P2NP13 J620_SCR 411390.9 4491632.8 1540.44 0.079220 7.62 634.26 13.97 0.61
P2NP14 J620_SCR 411396.5 4491632.8 1540.22 0.079220 7.62 634.26 13.97 0.61
P2NP15 J620_SCR 411402.1 4491632.7 1540 0.079220 7.62 634.26 13.97 0.61
P2NP16 J620_SCR 411407.5 4491632.7 1539.79 0.079220 7.62 634.26 13.97 0.61
P2NP17 J620_SCR 411413.3 4491632.7 1539.56 0.079220 7.62 634.26 13.97 0.61
P2NP18 J620_SCR 411418.7 4491632.6 1539.36 0.079220 7.62 634.26 13.97 0.61
P4NP01 J620_SCR 411313.2 4491580.8 1543.07 0.079220 7.62 634.26 13.97 0.61
P4NP02 J620_SCR 411318.9 4491580.7 1542.9 0.079220 7.62 634.26 13.97 0.61
P4NP03 J620_SCR 411324.5 4491580.7 1542.74 0.079220 7.62 634.26 13.97 0.61
P4NP04 J620_SCR 411330.0 4491580.7 1542.59 0.079220 7.62 634.26 13.97 0.61
P4NP05 J620_SCR 411335.6 4491580.6 1542.45 0.079220 7.62 634.26 13.97 0.61
P4NP06 J620_SCR 411341.0 4491580.6 1542.33 0.079220 7.62 634.26 13.97 0.61
P4NP07 J620_SCR 411346.5 4491580.6 1542.22 0.079220 7.62 634.26 13.97 0.61
P4NP08 J620_SCR 411352.3 4491580.5 1542.1 0.079220 7.62 634.26 13.97 0.61
P4NP09 J620_SCR 411357.8 4491580.5 1541.98 0.079220 7.62 634.26 13.97 0.61
P4NP10 J620_SCR 411374.0 4491580.4 1541.6 0.079220 7.62 634.26 13.97 0.61

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-14
ID Description X Coordinate (m)
Y Coordinate (m)
Elevation
(m)
Emission
Rate (g/s)
Stack Height (m)
Stack Temp. (K)
Stack Velocity (m/s)
Stack Diameter (m)
P4NP11 J620_SCR 411379.6 4491580.4 1541.48 0.079220 7.62 634.26 13.97 0.61
P4NP12 J620_SCR 411385.2 4491580.4 1541.36 0.079220 7.62 634.26 13.97 0.61
P4NP13 J620_SCR 411390.7 4491580.3 1541.23 0.079220 7.62 634.26 13.97 0.61
P4NP14 J620_SCR 411396.3 4491580.3 1541.08 0.079220 7.62 634.26 13.97 0.61
P4NP15 J620_SCR 411401.8 4491580.3 1540.91 0.079220 7.62 634.26 13.97 0.61
P4NP16 J620_SCR 411407.3 4491580.2 1540.72 0.079220 7.62 634.26 13.97 0.61
P4NP17 J620_SCR 411413.0 4491580.2 1540.51 0.079220 7.62 634.26 13.97 0.61
P4NP18 J620_SCR 411418.5 4491580.2 1540.29 0.079220 7.62 634.26 13.97 0.61
P5NP01 J620_SCR 411313.0 4491527.9 1543.27 0.079220 7.62 634.26 13.97 0.61
P5NP02 J620_SCR 411318.7 4491527.9 1543.12 0.079220 7.62 634.26 13.97 0.61
P5NP03 J620_SCR 411324.2 4491527.8 1542.99 0.079220 7.62 634.26 13.97 0.61
P5NP04 J620_SCR 411329.7 4491527.7 1542.87 0.079220 7.62 634.26 13.97 0.61
P5NP05 J620_SCR 411335.3 4491527.8 1542.75 0.079220 7.62 634.26 13.97 0.61
P5NP06 J620_SCR 411340.8 4491527.7 1542.65 0.079220 7.62 634.26 13.97 0.61
P5NP07 J620_SCR 411346.4 4491527.7 1542.55 0.079220 7.62 634.26 13.97 0.61
P5NP08 J620_SCR 411352.0 4491527.6 1542.45 0.079220 7.62 634.26 13.97 0.61
P5NP09 J620_SCR 411357.6 4491527.6 1542.34 0.079220 7.62 634.26 13.97 0.61
P5NP10 J620_SCR 411373.7 4491527.5 1541.98 0.079220 7.62 634.26 13.97 0.61
P5NP11 J620_SCR 411379.2 4491527.5 1541.85 0.079220 7.62 634.26 13.97 0.61
P5NP12 J620_SCR 411384.8 4491527.4 1541.72 0.079220 7.62 634.26 13.97 0.61
P5NP13 J620_SCR 411390.3 4491527.4 1541.59 0.079220 7.62 634.26 13.97 0.61
P5NP14 J620_SCR 411395.9 4491527.4 1541.47 0.079220 7.62 634.26 13.97 0.61
P5NP15 J620_SCR 411401.5 4491527.3 1541.36 0.079220 7.62 634.26 13.97 0.61
P5NP16 J620_SCR 411406.9 4491527.3 1541.24 0.079220 7.62 634.26 13.97 0.61
P5NP17 J620_SCR 411412.7 4491527.3 1541.08 0.079220 7.62 634.26 13.97 0.61
P5NP18 J620_SCR 411418.1 4491527.2 1540.93 0.079220 7.62 634.26 13.97 0.61
Table A-8. CO Capped Point Source Input Parameters
ID Description X Coordinate
(m)
Y Coordinate
(m)
Elevatio
n (m)
Emission
Rate (g/s)
Stack Height
(m)
Stack Temp.
(K)
Stack Velocity
(m/s)
Stack Diameter
(m)
BOIL1 Hot Water Boiler 411519.2 4492181.3 1531.66 0.020753 2.44 435.93 7.45 0.15

Novva SLC Common, LLC. | NO2, PM10, and CO Modeling Analysis Trinity Consultants A-15

Table A-9. Polygon Buildings.
ID Description X Coordinate
(m)
Y Coordinate
(m) Elevation (m) Height (m)
BLDG1 Building1 411538.3 4491829.9 1534.77 3.81
OFFICE2 - 411499.0 4492230.4 1531.89 4.43
BLDG2 Building 2 411358.0 4492205.8 1535.74 3.81
BLDG3 Building 3 411670.5 4491811.0 1531.78 3.81
OFFICE1 - 411496.2 4492173.1 1532.34 3.81
P3N - 411310.9 4491674.6 1541.77 6.10
PN2 - 411310.5 4491610.7 1543.03 6.10
PN4 - 411310.2 4491569.3 1543.17 6.10
PN5 - 411309.8 4491505.4 1543.44 6.10

NOVVA SLC Common, LLC. | Notice of Intent Air Permit Application Trinity Consultants
APPENDIX D. EMISSION CALCULATION SUPPORTING DOCUMENTS

Page 32
Equipment Sales Contract #: 70463
11. Apr. 2024
Page 33
Equipment Sales Contract #: 70463
11. Apr. 2024
Page 34
Equipment Sales Contract #: 70463
11. Apr. 2024

12.02.2024/HT( (EDFB) TS JGS 620 J715 13800V VoltaGrid Mobile 22Aug23-Rev02 Copyright ©(rg) 1/55

Technical Description, Rev01
Genset
JGS 620 GS-N.L
Grid Parallel with Island Operation

dyn. GC Profile 1 (150ms/30%)
Volta Grid Mobile Genset JGS 620 J715, 13800V
The ratings in the specification are valid for full load operation at a site installation of 3280 ft (1000 m) and an air intake
temperature of T1 < 86F (30C). At T1 > 86F (30C), an output deration of approximately 0.25%/F (0.45%/C) will occur

Electrical output @ 86F (PF = 1.0 / 0.86*) 3310 / 3291 kW el.
@ 104F (PF = 1.0 / 0.86*) 3156 / 3142 kW el.
@ 122F (PF = 1.0 / 0.86*) 3002 / 2995 kW el.
@ 77F (PF = 1.0 / 0.84*) 3310 / 3288 kW el.

* = PF for full load operation must be limited to the value stated when operating at given temperature

12.02.2024/HT( (EDFB) TS JGS 620 J715 13800V VoltaGrid Mobile 22Aug23-Rev02 Copyright ©(rg) 15/55

▪ 1640 ft (500 m) < Site Elevation < 3280 ft (1000 m)
For site elevations between 1640 ft (500 m) and 3280 ft (1000 m), 100% full load operations can
occur provided the maximum air intake temperatures is adjusted based on the relationship of

T1 < (104F – (1 F for every 91 ft above 1640 ft))
T1 < (40C – (1 C for every 50 m above 500 m)).

Summarized:
• At 1640 ft (500 m), 100% full genset output can be achieved up to an air intake temperature
of T1 < 104 F (40 C).
• At 2460 ft (750 m), 100% full genset output can be achieved up to an air intake temperature
of T1 < 95F (35 C).
• At 3280 ft (1000 m), 100% full genset output can be achieved up to an air intake temperature
of T1 < 86F (30 C).

At the noted elevation, should the noted T1 maximum be exceeded, a full load output derating of
approximately 0.25%/F (0.45%/C) will occur for T1 > max temp.

- Site Elevation = 3280 ft (1000 m) (Guarantee Point)
At a site elevation of 3280 ft (1000 m), 100% Full genset operation will occur at an air intake
temperature of T1 < 86F (30 C). At T1 > 86 F (30C), a full load output deration of approximately
0.25%/F (0.45%/C) will occur.

- 3280 ft (1000 m) < Site Elevation < 5905 ft (1800 m)
For site elevations between 3280 ft (1000 m) and 5905 ft (1800 m), full genset output operations
must be derated. The relationship for elevations effect on engine full load capability is the
relationship

Full Load Output = 100% - ( 0.85% for every 328 ft above 3280 ft)
Full Load Output = 100% - ( 0.85% for every 100m above 1000m)

The full load output will occur at an engine ambient air intake temperatures of T1 < 86 F(30 C).

Summarized:
• At 3280 ft (1000 m) and an engine air intake temperature T1 < 86 F (30 C), standard 100%
full output will be possible
• At 4593 ft (1400 m) and an engine air intake temperature T1 < 86F (30 C), full output will be
96.6% of the standard rating.
• At 5905 ft (1800 m) and an engine air intake temperature T1 < 86 F (30 C), full output will be
93.2% of the standard rating.

At the noted elevation, should air intake temperature be T1 > 86 F (30 C), the noted output rating will
derate by approximately 0.25%/F (0.45%/C).