DAQ-2025-001464

DAQE-AN141800013-25

{{$d1 }}

Charlie Hill
eBay Inc.
6614 West Crimson View Drive
South Jordan, UT 84095
[e-mail]

Dear Mr. Hill:

Re: Approval Order: Administrative Amendment to Approval Order DAQE-AN141800011-21 to
Update Operational Hours and the Equipment List
Project Number: N141800013

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on July 27,
2023. eBay Inc. 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.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:JJ:jg

cc: Salt Lake County Health Department

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Tim Davis
Interim Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

March 11, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

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APPROVAL ORDER
DAQE-AN141800013-25
Administrative Amendment to Approval Order
DAQE-AN141800011-21 to Update Operational Hours and
the Equipment List

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

Issued to
eBay Inc.- SLC Data Center

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

March 11, 2025
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 4
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 8
ACRONYMS ................................................................................................................................. 9

DAQE-AN141800013-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
eBay Inc. eBay Inc. - SLC Data Center

Mailing Address Physical Address
6614 West Crimson View Drive 6614 West Crimson View Drive
South Jordan, UT 84095 South Jordan, UT 84095

Source Contact UTM Coordinates
Name: Charlie Hill 411,299 m Easting
Phone: [phone],490,858 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 7374 (Computer Processing & Data Preparation & Processing Services)

SOURCE INFORMATION
General Description
eBay SLC Data Center (eBay) is a computer data center located in South Jordan. The facility consists of
diesel-fired emergency backup generators that provide electricity to the facility's data servers and backup
storage devices in the event of an emergency, diesel-powered fire pump engines, and cooling towers.

NSR Classification
Administrative Amendment

Source Classification
Located in Salt Lake City UT PM2.5 NAA, Salt Lake County SO2 NAA
Salt Lake County
Airs Source Size: SM

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
DAQE-AN141800013-25
Page 4

Project Description
eBay has submitted an NOI to update the operational hours of several diesel-fired generators, relocate two
(2) generators, remove two (2) diesel-fired emergency generators, and remove the Bloom Energy Servers
from the equipment list. These updates will reduce the PTE of the facility below the 50 TPY major source
threshold under the ozone non-attainment area reclassification.

SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent -38824 3670.00
Carbon Monoxide -2.11 6.68
Nitrogen Oxides -9.02 45.55
Particulate Matter - PM10 0.28 2.94
Particulate Matter - PM2.5 -1.96 0.66
Sulfur Oxides -0.06 0.06
Volatile Organic Compounds -0.31 1.44

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Benzene (Including Benzene From Gasoline) (CAS #71432) 10
Generic HAPs (CAS #GHAPS) -180 60
Change (TPY) Total (TPY)
Total HAPs -0.08 0.04

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8]
DAQE-AN141800013-25
Page 5

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]

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

SECTION II: PERMITTED EQUIPMENT
II.A THE APPROVED EQUIPMENT II.A.1 Data Center Computer data center
II.A.2 Cooling Tower Plants (2) 1) 35 MW cooling capacity 2) 6 MW cooling capacity II.A.3 Fire System Pump Engines (2) FP1: Manufacturer: Caterpillar Rating: 100 kW Fuel: Diesel FP2: Manufacturer: John Deere Rating: 64 kW Fuel: Diesel
II.A.4 Emergency Generator Engines - SLC01 Manufacturer: Detroit Diesel Fuel: Diesel G1 rating 3.25 MW G2 rating 3.25 MW G3 rating 3.25 MW G4 rating 3.25 MW G5 rating 3.25 MW G6 rating 3.25 MW G7 rating 3.25 MW
DAQE-AN141800013-25
Page 6

II.A.5 Emergency Generator Engines - SLC02 Manufacturer: Caterpillar Type: Tier 2 or better Fuel: Diesel G8 rating 3.1 MW G9 rating 3.0 MW G10 rating 3.0 MW G11 rating 3.0 MW G12 rating 3.0 MW G13 rating 3.0 MW G14 rating 3.0 MW G24 rating 2.5 MW G25 rating 2.5 MW
II.A.6 Emergency Generator Engines - SLC03
Manufacturer: Caterpillar

Type: Tier 2 or better with manufacturer year October 2016 or newer Fuel: Diesel
G15 rating 2.0 MW
G16 rating 2.0 MW G17 rating 1.5 MW
G18 rating 1.5 MW
G19 rating 2.0 MW G20 rating 2.0 MW
G21 rating 2.0 MW
G22 rating 2.0 MW G23 rating 1.0 MW
G26 rating 2.0 MW
G27 rating 2.0 MW G28 rating 2.0 MW
G29 rating 2.0 MW
G32 rating 750 kW G33 rating 750 kW

SECTION II: SPECIAL PROVISIONS
II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Source-Wide Requirements
II.B.1.a Visible emissions from any stationary point associated with the source or with the control facilities shall not exceed 20% opacity. [R307-305-3, R307-401-8]
II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-305-5]

DAQE-AN141800013-25
Page 7

II.B.2 Emergency Generator Engine Requirements II.B.2.a The owner/operator shall not operate each emergency engine beyond the hours listed below for
non-emergency purposes. There is no time limit on the use of the engines during emergencies. Engines G01-G14, G17-29, and G32-33 - 60 hours per calendar year
All other engines - 100 hours per calendar year.
[40 CFR 60 Subpart ZZZZ, R307-401-8]
II.B.2.b For the emergency generator engines, operations during engine operator training, engine maintenance, and engine compliance testing (OMT operations) shall be conducted as follows: 1) All engine compliance testing shall be conducted as outlined in 40 CFR 60 Subpart IIII or 40 CFR 63 Subpart ZZZZ as appropriate. 2) Testing of up to four (4) generators at the same time may occur once per month from 8 am to 6 pm for 30 minutes. 3) In addition to monthly OMT operation, each generator may be tested for one (1) hour once per calendar year from 8 am to 6 pm. These restrictions do not apply to the fire pump engines (II.A.3). [R307-401-8]
II.B.2.c A non-resettable hour meter shall be installed and operational on all engines.
[R307-401-8, 40 CFR 63 Subpart ZZZZ]
II.B.2.d To determine compliance with the calendar year total, the owner/operator shall calculate a monthly total by the 20th day of each month. The sum of these monthly totals from January through December of any given year, inclusive, shall constitute the calendar year total. 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.e The owner/operator shall only use diesel fuel (fuel oil #1, #2, or diesel fuel oil additives) in any emergency generator engines located on site. All diesel burned shall meet the definition of
ultra-low sulfur diesel (ULSD) and contain no more than 15 ppm sulfur.
[40 CFR 60 Subpart IIII]

II.B.2.e.1 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-AN141800013-25
Page 8

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN141800011-21 dated January 7, 2021 Is Derived From NOI dated July 27, 2023 Incorporates Additional Information dated November 21, 2024

DAQE-AN141800013-25
Page 9

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-

RN141800013 February 13, 2025 Charlie Hill
eBay Inc. 6614 West Crimson View Drive South Jordan, UT 84095
[e-mail] Dear Charlie Hill,
Re: Engineer Review - Administrative Amendment: Administrative Amendment of Approval Order DAQE-AN141800011-21 to Update Operational Hours and the Equipment List Project Number: N141800013 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 (NSR) permitting program. eBay Inc. should complete this review within 10 business days of receipt. eBay Inc. 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 Approval Order (AO) for signature by the DAQ Director. If eBay Inc. does not respond to this letter within 10 business days, the project will move forward without source concurrence. If eBay Inc. has concerns that cannot be resolved and the project becomes
stagnant, the DAQ Director may issue an Order prohibiting construction. Approval Signature _____________________________________________________________
(Signature & Date)
195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of Environmental Quality
Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director
State of Utah
SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION
Project Number N141800013 Owner Name eBay Inc. Mailing Address 6614 West Crimson View Drive
South Jordan, UT, 84095 Source Name eBay Inc.- SLC Data Center
Source Location 6614 West Crimson View Drive South Jordan, UT 84095
UTM Projection 411,299 m Easting, 4,490,858 m Northing UTM Datum NAD83 UTM Zone UTM Zone 12 SIC Code 7374 (Computer Processing & Data Preparation & Processing Services) Source Contact Charlie Hill Phone Number [phone] Email [e-mail] Billing Contact Charlie Hill
Phone Number 480.217.8872 Email [e-mail]
Project Engineer John Jenks, Engineer Phone Number [phone] Email [e-mail]
Notice of Intent (NOI) Submitted July 27, 2023 Date of Accepted Application April 1, 2024

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 2
SOURCE DESCRIPTION General Description
eBay SLC Data Center (eBay), is a computer data center located in South Jordan. The facility consists of diesel-fired emergency backup generators that provide electricity to the facility's data servers and backup storage devices in the event of an emergency, diesel-powered fire pump
engines, and cooling towers. NSR Classification: Administrative Amendment Source Classification Located in , Salt Lake City UT PM2.5 NAA, Salt Lake County SO2 NAA, Salt Lake County Airs Source Size: B Applicable Federal Standards
NSPS (Part 60), A: General Provisions NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion Engines
MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
Project Proposal Administrative Amendment of Approval Order DAQE-AN141800011-21 to Update Operational Hours and the Equipment List Project Description
eBay has submitted a NOI to update the operational hours of several diesel-fired generators, relocate two generators, remove two diesel-fired emergency generators, and remove the Bloom Energy Servers from the equipment list. These updates will reduce the PTE of the facility below the 50 TPY major source threshold under the ozone non-attainment area reclassification. EMISSION IMPACT ANALYSIS
In this project, two engines are being relocated (G26 and G27). These engines are now occupying the previous locations of G30 and G31 (which have been removed). The source elected to re-submit its previous modeling with updates. This modeling has been reviewed by UDAQ and the results are outlined in modeling memo MN141800013-25. The modeling memo also includes suggested permit language to be included under the Terms and Conditions in the AO. ·Testing of up to four (4) generators at the same time may occur once per month from 8 am to 6 pm for 30 minutes. ·In addition to monthly testing, each generator may be tested for 1 hour once per year from 8 am to 6 pm.
This language has been added to condition II.B.2.b. [Last updated February 4, 2025]

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 3
SUMMARY OF EMISSIONS
The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible.
Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent -38824 3670.00 Carbon Monoxide -2.11 6.68
Nitrogen Oxides -9.02 45.55
Particulate Matter - PM10 0.28 2.94
Particulate Matter - PM2.5 -1.96 0.66
Sulfur Oxides -0.06 0.06
Volatile Organic Compounds -0.31 1.44 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Benzene (Including Benzene From Gasoline) (CAS #71432) 10
Generic HAPs (CAS #GHAPS) -180 60
Change (TPY) Total (TPY)
Total HAPs -0.08 0.04
Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 4
Review of BACT for New/Modified Emission Units 1. BACT review regarding no BACT review required
As this project does not include any new equipment and no physical changes will occur to existing equipment, no BACT review is required. Although two engines are being relocated, they are not being physically modified, and their method of operation (as emergency generators) will remain
unchanged. [Last updated February 4, 2025]
SECTION I: GENERAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label):
I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101]
I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]
I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]
I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 5
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 Data Center Computer data center
II.A.2 Cooling Tower Plants (2) 1. 35 MW cooling capacity 2. 6 MW cooling capacity
II.A.3 Fire System Pump Engines (2) FP1: Manufacturer: Caterpillar Rating:100 kW Fuel: Diesel
FP2:
Manufacturer: John Deere Rating:64 kW Fuel: Diesel

II.A.4 Emergency Generator Engines - SLC01 Manufacturer: Detroit Diesel Fuel: Diesel G1 rating 3.25 MW G2 rating 3.25 MW G3 rating 3.25 MW G4 rating 3.25 MW G5 rating 3.25 MW G6 rating 3.25 MW G7 rating 3.25 MW

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 6
II.A.5 Emergency Generator Engines - SLC02 Manufacturer: Caterpillar
Type: Tier 2 or better Fuel: Diesel G8 rating 3.1 MW
G9 rating 3.0 MW G10 rating 3.0 MW G11 rating 3.0 MW
G12 rating 3.0 MW G13 rating 3.0 MW G14 rating 3.0 MW G24 rating 2.5 MW G25 rating 2.5 MW
II.A.6 Emergency Generator Engines - SLC03 Manufacturer: Caterpillar Type: Tier 2 or better with manufacturer year October 2016 or newer.
Fuel: Diesel G15 rating 2.0 MW G16 rating 2.0 MW G17 rating 1.5 MW G18 rating 1.5 MW G19 rating 2.0 MW G20 rating 2.0 MW G21 rating 2.0 MW G22 rating 2.0 MW G23 rating 1.0 MW G26 rating 2.0 MW
G27 rating 2.0 MW G28 rating 2.0 MW G29 rating 2.0 MW
G32 rating 750 kW G33 rating 750 kW

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 Source-Wide Requirements II.B.1.a Visible emissions from any stationary point associated with the source or with the control facilities shall not exceed 20% opacity. [R307-305-3, R307-401-8]

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 7
II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-305-5]
II.B.2 Emergency Generator Engine Requirements II.B.2.a NEW The owner/operator shall not operate each emergency engine beyond the hours listed below for non-emergency purposes. There is no time limit on the use of the engines during
emergencies.
Engines G01-G14, G17-29 and G32-33 - 60 hours per calendar year All other engines - 100 hours per calendar year. [40 CFR 60 Subpart ZZZZ, R307-401-8] II.B.2.b NEW For the emergency generator engines - operations during engine operator training, engine maintenance, and engine compliance testing (OMT operations) shall be conducted as follows:
1. All engine compliance testing shall be conducted as outlined in 40 CFR 60 Subpart IIII or
40 CFR 63 Subpart ZZZZ as appropriate. 2. Testing of up to four (4) generators at the same time may occur once per month from 8 am to 6 pm for 30 minutes.
3. In addition to monthly OMT operation, each generator may be tested for one hour once per calendar year from 8 am to 6 pm. These restrictions do not apply to the fire pump engines (II.A.3). [R307-401-8] II.B.2.c A non-resettable hour meter shall be installed and operational on all engines. [R307-401-8, 40 CFR 63 Subpart ZZZZ]
II.B.2.d NEW To determine compliance with the calendar year total, the owner/operator shall calculate a monthly total by the 20th day of each month. The sum of these monthly totals from January through December of any given year, inclusive, shall constitute the calendar year total.
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.e The owner/operator shall only use diesel fuel (fuel oil #1, #2 or diesel fuel oil additives) in any emergency generator engines located on site. All diesel burned shall meet the definition of ultra-low sulfur diesel (ULSD), and contain no more than 15 ppm sulfur. [40 CFR 60 Subpart IIII] II.B.2.e.1 NEW To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements. [R307-401-8]

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 8
PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the
following documents: Supersedes DAQE-AN141800011-21 dated January 7, 2021
Is Derived From Source Submitted NOI dated July 27, 2023 Incorporates Additional Information Received dated November 21, 2024
REVIEWER COMMENTS 1. Comment regarding Project changes: This project involves the following:
1) increasing hours of operation for G15 and G16 from 66 operational hours per year to 100
operational hours per year, 2) decreasing hours of operation for G01-G14, G17-G29, and G32-33 from 66 operational hours per year to 60 operational hours per year, 3) relocation of generators G26 and G27 to G30 and G31 locations, 4) removal of G30 and G31 from the permit, 5) removing the Bloom Energy Servers.
6) incorporating the relocation of G09, this was previously approved under DAQE-GN141800012-21. These changes require updating the equipment list (Section II.A), and the following conditions: II.B.2.a - removal of old hours of operation language and simplifying the hours of operation
limitations II.B.2.b - updating the language based on modeling suggestions. The equipment list has been reorganized showing all equipment in the correct location (by building number). The diesel storage tanks have been delisted as these tanks are integral with the individual
engine and do not need a separate listing. Condition I.8 is no longer needed and has been removed. [Last updated February 13, 2025]
2. Comment regarding Changes in emissions: With this project, total emissions at the facility are re-estimated as 45.55 tpy of NOx (the pollutant of
concern for major source considerations. All other pollutants are already below the expected 50 tpy threshold for the ozone NAA redesignation major source level. This facility will retain classification as a minor source. [Last updated February 4, 2025]

Engineer Review N141800013: eBay Inc.- SLC Data Center February 13, 2025 Page 9
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
DAQE-MN141800013-25 M E M O R A N D U M

TO: John Jenks, NSR Engineer FROM: Dave Prey, Air Quality Modeler
DATE: January 22, 2025 SUBJECT: Modeling Analysis Review for the Notice of Intent for eBay Inc. – South Jordan Data Center, Salt Lake County, Utah __________________________________________________________________________________________________ This is not a Major Prevention of Significant Deterioration (PSD) Source. I. OBJECTIVE
eBay Inc. (eBay) is seeking a modified approval order for their South Jordan Data Center, located
in Salt Lake County, Utah. eBay has requested to add additional emergency generators and replace some existing generators.
This report, prepared by the Staff of the New Source Review Section (NSR), contains a review of
the air quality impact analysis (AQIA) including the information, data, assumptions and modeling results used to determine if the facility would be in compliance with State and Federal concentration standards. II. APPLICABLE RULE(S)
Utah Air Quality Rules: R307-401-6 Condition for Issuing an Approval Order R307-410-3 Use of Dispersion Models R307-410-4 Modeling of Criteria Pollutants in Attainment Areas III. MODELING METHODOLOGY
A. Applicability Emissions from the facility include PM10, NOx, CO, SO2, and HAPs. This modeling is part of a modified approval order. The total emission rate for NOx warranted a modeling review to demonstrate compliance with the NAAQS. Modeling was performed by the UDAQ.

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-MN141800013-25 Page 2

B. Assumptions 1. Topography/Terrain

The Plant is at an elevation 5077 feet with terrain features that have little affect on concentration predictions.
a. Zone: 12 b. Approximate Location: UTM (NAD83): 411308 meters East 4490965 meters North
2. Urban or Rural Area Designation After a review of the appropriate 7.5 minute quadrangles, it was concluded the area is “rural” for air modeling purposes. 3. Ambient Air
It was determined the Plant boundary used in the AQIA meets the State’s definition of ambient air.
4. Building Downwash The source was modeled with the AERMOD model. All structures at the plant were used in the model to account for their influence on downwash. 5. Meteorology
Five years of off-site surface and upper air data were used in the analysis consisting of the following:
Surface – Salt Lake Airport, UT NWS: 2017-2021 Upper Air – Salt Lake Airport, UT NWS: 2017-2021 6. Background The background concentrations were based on a 3-year average seasonal-diurnal NO2 concentration measured in Herriman, Utah.

DAQE-MN141800013-25 Page 3
7. Receptor and Terrain Elevations The modeling domain consisted of receptors including property boundary receptors. Receptor points representing actual terrain elevations from the area were used in the
analysis. 8. Model and Options The State-accepted AERMOD model was used to predict air pollutant concentrations under a simple/complex terrain/wake effect situation. In quantifying concentrations, the regulatory default option was selected by the Applicant. 9. Air Pollutant Emission Rates

Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) min/test hrs/year
G01 411272 4490966 7.25 0.36 30 100
G02 411284 4490966 7.25 0.36 30 100
G03 411295 4490966 7.25 0.36 30 100
G04 411308 4490966 7.25 0.36 30 100
G05 411319 4490966 7.25 0.36 30 100
G06 411331 4490966 7.25 0.36 30 100
G07 411343 4490966 7.25 0.36 30 100
G08 411326 4490763 5.68 0.28 30 100
G09 411213 4490751 5.68 0.28 30 100
G10 411195 4490755 5.68 0.28 30 100
G11 411383 4490796 5.68 0.28 30 100
G12 411383 4490802 5.68 0.28 30 100
G13 411384 4490822 5.68 0.28 30 100
G14 411384 4490828 5.68 0.28 30 100
G24 411315 4490726 4.40 0.22 30 100
G25 411321 4490726 4.40 0.22 30 100
G26 411326 4490727 4.83 0.24 30 100
G27 411332 4490727 4.83 0.24 30 100
G15 411130 4490924 0.00 0.00 30 100
G16 411131 4490918 4.83 0.24 30 100
G17 411131 4490911 4.83 0.24 30 100
G18 411131 4490905 4.16 0.21 30 100
G19 411130 4490899 4.16 0.21 30 100
G20 411130 4490892 4.83 0.24 30 100
G21 411130 4490886 4.83 0.24 30 100
DAQE-MN141800013-25 Page 4
G22 411130 4490879 4.83 0.24 30 100
G23 411131 4490873 4.83 0.24 30 100
G28 411130 4490971 2.75 0.14 30 100
G29 411130 4490964 4.83 0.24 30 100
G30 411130 4490957 4.83 0.24 30 100
G31 411130 4490951 4.83 0.24 30 100
G32 411131 4490944 4.83 0.24 30 100
G33 411131 4490937 2.63 0.13 30 100
Total 170.91 8.55
Nearby Sources NOVVA Inc.
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
BOIL1 411519 4492181 0.20 0.86 8760
GENN01 411449 4492171 8.84 0.44 100
GENN02 411449 4492167 8.84 0.44 100
GENN03 411449 4492164 8.84 0.44 100
GENN04 411449 4492161 8.84 0.44 100
GENN05 411461 4492137 7.33 0.37 100
GENN06 411461 4492128 7.33 0.37 100
GENN07 411461 4492124 7.33 0.37 100
GENN08 411461 4492119 7.33 0.37 100
GENN09 411461 4492116 7.33 0.37 100
GENN10 411461 4492107 7.33 0.37 100
GENN11 411461 4492103 7.33 0.37 100
GENN12 411461 4492094 7.33 0.37 100
GENN13 411460 4492081 8.32 0.42 100
GENN14 411460 4492073 8.45 0.42 100
GENN15 411460 4492068 8.45 0.42 100
GENN16 411460 4492060 8.54 0.43 100
GENN17 411460 4492050 7.33 0.37 100
GENN18 411460 4492044 7.33 0.37 100
GENN19 411460 4492038 7.33 0.37 100
GENN20 411460 4492030 7.33 0.37 100
GENN21 411460 4492020 15.67 0.78 100
GENN22 411459 4492014 15.67 0.78 100
DAQE-MN141800013-25 Page 5
GENN23 411459 4492009 15.67 0.78 100
GENN24 411459 4492005 15.67 0.78 100
GENN25 411459 4492000 15.67 0.78 100
GENN26 411459 4491989 15.67 0.78 100
GENN27 411459 4491977 15.67 0.78 100
GENN28 411459 4491969 15.67 0.78 100
GENN29 411459 4491963 15.67 0.78 100
GENN30 411459 4491955 15.67 0.78 100
GENN31 411458 4491948 15.67 0.78 100
GENN32 411458 4491931 8.54 0.43 100
GENN33 411458 4491915 7.33 0.37 100
GENN34 411458 4491906 7.33 0.37 100
GENN35 411457 4491894 7.33 0.37 100
GENN36 411457 4491884 7.33 0.37 100
OFFICE 411546 4492186 4.61 0.23 100
P3NP01 411316 4491686 0.15 0.64 8760
P3NP02 411321 4491686 0.15 0.64 8760
P3NP03 411327 4491686 0.15 0.64 8760
P3NP04 411332 4491686 0.15 0.64 8760
P3NP05 411338 4491686 0.15 0.64 8760
P3NP06 411343 4491686 0.15 0.64 8760
P3NP07 411349 4491686 0.15 0.64 8760
P3NP08 411355 4491686 0.15 0.64 8760
P3NP09 411360 4491686 0.15 0.64 8760
P3NP10 411373 4491686 0.15 0.64 8760
P3NP11 411378 4491686 0.15 0.64 8760
P3NP12 411384 4491686 0.15 0.64 8760
P3NP13 411389 4491686 0.15 0.64 8760
P3NP14 411395 4491686 0.15 0.64 8760
P3NP15 411401 4491686 0.15 0.64 8760
P3NP16 411406 4491686 0.15 0.64 8760
P3NP17 411412 4491686 0.15 0.64 8760
P3NP18 411417 4491686 0.15 0.64 8760
P2NP01 411315 4491633 0.15 0.64 8760
P2NP02 411321 4491633 0.15 0.64 8760
P2NP03 411327 4491633 0.15 0.64 8760
P2NP04 411332 4491633 0.15 0.64 8760
P2NP05 411338 4491633 0.15 0.64 8760
P2NP06 411343 4491633 0.15 0.64 8760
P2NP07 411349 4491633 0.15 0.64 8760
P2NP08 411354 4491633 0.15 0.64 8760
P2NP09 411360 4491633 0.15 0.64 8760
P2NP10 411372 4491633 0.15 0.64 8760
DAQE-MN141800013-25 Page 6
P2NP11 411378 4491633 0.15 0.64 8760
P2NP12 411384 4491633 0.15 0.64 8760
P2NP13 411389 4491633 0.15 0.64 8760
P2NP14 411395 4491633 0.15 0.64 8760
P2NP15 411400 4491633 0.15 0.64 8760
P2NP16 411406 4491633 0.15 0.64 8760
P2NP17 411411 4491633 0.15 0.64 8760
P2NP18 411417 4491633 0.15 0.64 8760
P4NP01 411315 4491581 0.15 0.64 8760
P4NP02 411321 4491581 0.15 0.64 8760
P4NP03 411326 4491581 0.15 0.64 8760
P4NP04 411332 4491581 0.15 0.64 8760
P4NP05 411337 4491581 0.15 0.64 8760
P4NP06 411343 4491581 0.15 0.64 8760
P4NP07 411348 4491581 0.15 0.64 8760
P4NP08 411354 4491581 0.15 0.64 8760
P4NP09 411360 4491581 0.15 0.64 8760
P4NP10 411372 4491580 0.15 0.64 8760
P4NP11 411378 4491580 0.15 0.64 8760
P4NP12 411383 4491580 0.15 0.64 8760
P4NP13 411389 4491580 0.15 0.64 8760
P4NP14 411394 4491580 0.15 0.64 8760
P4NP15 411400 4491580 0.15 0.64 8760
P4NP16 411405 4491580 0.15 0.64 8760
P4NP17 411411 4491580 0.15 0.64 8760
P4NP18 411417 4491580 0.15 0.64 8760
P5NP01 411315 4491528 0.15 0.64 8760
P5NP02 411321 4491528 0.15 0.64 8760
P5NP03 411326 4491528 0.15 0.64 8760
P5NP04 411332 4491528 0.15 0.64 8760
P5NP05 411337 4491528 0.15 0.64 8760
P5NP06 411343 4491528 0.15 0.64 8760
P5NP07 411348 4491528 0.15 0.64 8760
P5NP08 411354 4491528 0.15 0.64 8760
P5NP09 411359 4491528 0.15 0.64 8760
P5NP10 411372 4491528 0.15 0.64 8760
P5NP11 411377 4491528 0.15 0.64 8760
P5NP12 411383 4491527 0.15 0.64 8760
P5NP13 411388 4491527 0.15 0.64 8760
P5NP14 411394 4491527 0.15 0.64 8760
P5NP15 411400 4491527 0.15 0.64 8760
P5NP16 411405 4491527 0.15 0.64 8760
P5NP17 411411 4491527 0.15 0.64 8760
DAQE-MN141800013-25 Page 7
P5NP18 411416 4491527 0.15 0.64 8760
Total 382.59 65.82
Source
UTM Coordinates Modeled Emission Rates
Easting Northing PM10
(m) (m) (lb/hr) (tons/yr) hrs/year
BOIL1 411519 4492181 0.0149 0.065 8760
GENN01 411449 4492171 0.2577 0.013 100
GENN02 411449 4492167 0.2577 0.013 100
GENN03 411449 4492164 0.2577 0.013 100
GENN04 411449 4492161 0.2577 0.013 100
GENN05 411461 4492137 0.2679 0.013 100
GENN06 411461 4492128 0.2679 0.013 100
GENN07 411461 4492124 0.2679 0.013 100
GENN08 411461 4492119 0.2679 0.013 100
GENN09 411461 4492116 0.2679 0.013 100
GENN10 411461 4492107 0.2679 0.013 100
GENN11 411461 4492103 0.2679 0.013 100
GENN12 411461 4492094 0.2679 0.013 100
GENN13 411460 4492081 0.2679 0.013 100
GENN14 411460 4492073 0.3032 0.015 100
GENN15 411460 4492068 0.3032 0.015 100
GENN16 411460 4492060 0.5828 0.029 100
GENN17 411460 4492050 0.2679 0.013 100
GENN18 411460 4492044 0.2679 0.013 100
GENN19 411460 4492038 0.2679 0.013 100
GENN20 411460 4492030 0.2679 0.013 100
GENN21 411460 4492020 0.5953 0.030 100
GENN22 411459 4492014 0.5953 0.030 100
GENN23 411459 4492009 0.5953 0.030 100
GENN24 411459 4492005 0.5953 0.030 100
GENN25 411459 4492000 0.5953 0.030 100
GENN26 411459 4491989 0.5953 0.030 100
GENN27 411459 4491977 0.5953 0.030 100
DAQE-MN141800013-25 Page 8
GENN28 411459 4491969 0.5953 0.030 100
GENN29 411459 4491963 0.5953 0.030 100
GENN30 411459 4491955 0.5953 0.030 100
GENN31 411458 4491948 0.5953 0.030 100
GENN32 411458 4491931 0.5828 0.029 100
GENN33 411458 4491915 0.2679 0.013 100
GENN34 411458 4491906 0.2679 0.013 100
GENN35 411457 4491894 0.2679 0.013 100
GENN36 411457 4491884 0.2679 0.013 100
OFFICE 411546 4492186 0.0467 0.002 100
P3NP01 411316 4491686 0.0967 0.424 8760
P3NP02 411321 4491686 0.0967 0.424 8760
P3NP03 411327 4491686 0.0967 0.424 8760
P3NP04 411332 4491686 0.0967 0.424 8760
P3NP05 411338 4491686 0.0967 0.424 8760
P3NP06 411343 4491686 0.0967 0.424 8760
P3NP07 411349 4491686 0.0967 0.424 8760
P3NP08 411355 4491686 0.0967 0.424 8760
P3NP09 411360 4491686 0.0967 0.424 8760
P3NP10 411373 4491686 0.0967 0.424 8760
P3NP11 411378 4491686 0.0967 0.424 8760
P3NP12 411384 4491686 0.0967 0.424 8760
P3NP13 411389 4491686 0.0967 0.424 8760
P3NP14 411395 4491686 0.0967 0.424 8760
P3NP15 411401 4491686 0.0967 0.424 8760
P3NP16 411406 4491686 0.0967 0.424 8760
P3NP17 411412 4491686 0.0967 0.424 8760
P3NP18 411417 4491686 0.0967 0.424 8760
P2NP01 411315 4491633 0.0967 0.424 8760
P2NP02 411321 4491633 0.0967 0.424 8760
P2NP03 411327 4491633 0.0967 0.424 8760
P2NP04 411332 4491633 0.0967 0.424 8760
P2NP05 411338 4491633 0.0967 0.424 8760
P2NP06 411343 4491633 0.0967 0.424 8760
P2NP07 411349 4491633 0.0967 0.424 8760
DAQE-MN141800013-25 Page 9
P2NP08 411354 4491633 0.0967 0.424 8760
P2NP09 411360 4491633 0.0967 0.424 8760
P2NP10 411372 4491633 0.0967 0.424 8760
P2NP11 411378 4491633 0.0967 0.424 8760
P2NP12 411384 4491633 0.0967 0.424 8760
P2NP13 411389 4491633 0.0967 0.424 8760
P2NP14 411395 4491633 0.0967 0.424 8760
P2NP15 411400 4491633 0.0967 0.424 8760
P2NP16 411406 4491633 0.0967 0.424 8760
P2NP17 411411 4491633 0.0967 0.424 8760
P2NP18 411417 4491633 0.0967 0.424 8760
P4NP01 411315 4491581 0.0967 0.424 8760
P4NP02 411321 4491581 0.0967 0.424 8760
P4NP03 411326 4491581 0.0967 0.424 8760
P4NP04 411332 4491581 0.0967 0.424 8760
P4NP05 411337 4491581 0.0967 0.424 8760
P4NP06 411343 4491581 0.0967 0.424 8760
P4NP07 411348 4491581 0.0967 0.424 8760
P4NP08 411354 4491581 0.0967 0.424 8760
P4NP09 411360 4491581 0.0967 0.424 8760
P4NP10 411372 4491580 0.0967 0.424 8760
P4NP11 411378 4491580 0.0967 0.424 8760
P4NP12 411383 4491580 0.0967 0.424 8760
P4NP13 411389 4491580 0.0967 0.424 8760
P4NP14 411394 4491580 0.0967 0.424 8760
P4NP15 411400 4491580 0.0967 0.424 8760
P4NP16 411405 4491580 0.0967 0.424 8760
P4NP17 411411 4491580 0.0967 0.424 8760
P4NP18 411417 4491580 0.0967 0.424 8760
P5NP01 411315 4491528 0.0967 0.424 8760
P5NP02 411321 4491528 0.0967 0.424 8760
P5NP03 411326 4491528 0.0967 0.424 8760
P5NP04 411332 4491528 0.0967 0.424 8760
P5NP05 411337 4491528 0.0967 0.424 8760
P5NP06 411343 4491528 0.0967 0.424 8760
DAQE-MN141800013-25 Page 10
P5NP07 411348 4491528 0.0967 0.424 8760
P5NP08 411354 4491528 0.0967 0.424 8760
P5NP09 411359 4491528 0.0967 0.424 8760
P5NP10 411372 4491528 0.0967 0.424 8760
P5NP11 411377 4491528 0.0967 0.424 8760
P5NP12 411383 4491527 0.0967 0.424 8760
P5NP13 411388 4491527 0.0967 0.424 8760
P5NP14 411394 4491527 0.0967 0.424 8760
P5NP15 411400 4491527 0.0967 0.424 8760
P5NP16 411405 4491527 0.0967 0.424 8760
P5NP17 411411 4491527 0.0967 0.424 8760
P5NP18 411416 4491527 0.0967 0.424 8760
Total 20.93 31.27
Oracle
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
STCK1 412204 4491302 6.00 0.30 100
STCK2 412204 4491308 6.00 0.30 100
STCK3 412205 4491314 6.00 0.30 100
STCK4 412206 4491321 6.00 0.30 100
STCK5 412207 4491334 6.00 0.30 100
STCK6 412208 4491341 6.00 0.30 100
STCK7 412209 4491346 6.00 0.30 100
STCK8 412210 4491353 6.00 0.30 100
STCK9 412202 4491257 6.72 0.34 100
STCK10 412200 4491251 6.72 0.34 100
STCK11 412195 4491241 6.76 0.34 100
STCK12 412206 4491205 1.75 0.09 100
STCK1NL 412204 4491302 6.00 0.30 100
STCK2NL 412204 4491308 6.00 0.30 100
STCK3NL 412205 4491314 6.00 0.30 100
STCK4NL 412206 4491321 6.00 0.30 100
STCK5NL 412207 4491334 6.00 0.30 100
DAQE-MN141800013-25 Page 11
STCK6NL 412208 4491341 6.00 0.30 100
STCK7NL 412209 4491346 6.00 0.30 100
STCK8NL 412210 4491353 6.00 0.30 100
STCK9NL 412202 4491257 6.72 0.34 100
STCK10NL 412200 4491251 6.72 0.34 100
STCK11NL 412195 4491241 6.76 0.34 100
STCK12NL 412206 4491205 1.75 0.09 100
OA_FPUMP 412203 4491281 0.96 0.05 100
Total 140.91 7.05
Danone
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
HEATEXCH 412216 4492748 6.15 26.94 8760
BOILER4 412213 4492725 0.34 1.49 8760
Total 6.49 28.42 SME Industries
x
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
GEN 412943 4492242 10.70 0.54 100
WELDING 412651 4492163 0.00 0.00 8760
PLASMA96 412698 4492190 0.87 3.82 8760
PLASMA60 412698 4492180 0.87 3.82 8760
FICEP 412585 4491991 0.87 3.82 8760
ROBOT 412657 4492214 0.87 3.82 8760
PLASMA20 412679 4492107 0.00 0.00 8760
OA_FPUMP 412203 4491281 0.96 4.20 8760
Total 15.15 20.03
DAQE-MN141800013-25 Page 12
10. Source Location and Parameters
Source Type
Source Parameters
Elev, Ht Temp Flow Dia
(ft) (m) (ft) (K) (m/s) (m)
G01 POINT 5087.6 5.7 18.7 668 16.56 0.71
G02 POINT 5087.6 5.7 18.7 668 16.56 0.71
G03 POINT 5087.6 5.7 18.7 668 16.56 0.71
G04 POINT 5087.6 5.7 18.7 668 16.56 0.71
G05 POINT 5087.6 5.7 18.7 668 16.56 0.71
G06 POINT 5087.6 5.7 18.7 668 16.56 0.71
G07 POINT 5087.6 5.7 18.7 668 16.56 0.71
G08 POINT 5087.6 8.7 28.5 713 21.76 0.61
G09 POINT 5087.6 6.7 22.0 713 21.76 0.61
G10 POINT 5087.6 6.7 22.0 713 21.76 0.61
G11 POINT 5087.6 6.7 22.0 713 21.76 0.61
G12 POINT 5087.6 6.7 22.0 713 21.76 0.61
G13 POINT 5087.6 6.7 22.0 713 21.76 0.61
G14 POINT 5087.6 6.7 22.0 713 21.76 0.61
G24 POINT 5087.6 6.1 20.0 621 22.02 0.46
G25 POINT 5087.6 6.1 20.0 621 22.02 0.46
G26 POINT 5087.6 6.1 20.0 614 19.14 0.46
G27 POINT 5087.6 6.1 20.0 614 19.14 0.46
G15 POINT 5103.3 8.2 26.9 614 0.46
G16 POINT 5103.3 8.2 26.9 614 19.14 0.46
G17 POINT 5103.3 7.2 23.6 629 19.14 0.46
G18 POINT 5103.3 7.2 23.6 629 14.21 0.46
G19 POINT 5103.3 8.2 26.9 614 14.21 0.46
G20 POINT 5103.3 8.2 26.9 614 19.14 0.46
G21 POINT 5103.3 8.2 26.9 614 19.14 0.46
G22 POINT 5103.3 8.2 26.9 614 19.14 0.46
G23 POINT 5103.3 6.7 22.0 633 19.14 0.46
G28 POINT 5103.3 8.2 26.9 614 4.46 0.46
G29 POINT 5103.3 8.2 26.9 614 19.14 0.46
G30 POINT 5103.3 8.2 26.9 614 19.14 0.46
G31 POINT 5103.3 8.2 26.9 614 19.14 0.46
G32 POINT 5103.3 7.2 23.6 706 19.14 0.51
G33 POINT 5103.3 7.2 23.6 706 7.42 0.51

IV. RESULTS AND CONCLUSIONS
DAQE-MN141800013-25 Page 13
A. National Ambient Air Quality Standards The below table provides a comparison of the predicted total air quality concentrations with the NAAQS. The predicted total concentrations are less than the NAAQS.

Air Pollutant Period Prediction Class II Significant Impact Level
Background Nearby Sources* Total NAAQS Percent
(μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) NAAQS
NO2 1-Hour 13.2 7.5 23.0 106.4 142.6 188 75.9%

V. PERMIT CONDITIONS The following suggested permit language should be included under the Terms and Conditions in the AO.
• Testing of up to four (4) generators at the same time may occur once per month from 8 am to 6
pm for 30 minutes.
• In addition to monthly testing, each generator may be tested for 1 hour once per year from 8 am to 6 pm.

DP:jg

Confidential

Intended for Utah Division for Air Quality
Prepared for
eBay
South Jordan, Utah
Prepared by Ramboll Americas Engineering Solutions
Salt Lake City, UT
Project Number
1940109969
Date
November 2024

AIR DISPERSION MODELING REPORT
EBAY SLC DATA CENTER

Air Dispersion Modeling Report
eBay SLC Data Center
Contents i Ramboll
Confidential
CONTENTS
1. INTRODUCTION 1
2. UTAH DAQ MODELING REQUIREMENTS 2
3. AIR QUALITY ANALYSIS APPROACH 4
3.1 Significance Analysis 4
3.2 NAAQS Analysis 5
4. MODELING METHODOLOGY, SETTINGS, AND INPUTS 6
4.1 Model Selection and Settings 6
4.1.1 NO2 Modeling Approach 6
4.2 Modeled Sources and Release Parameters 6
4.3 Building Downwash 7
4.4 Good Engineering Practice Stack Height Analysis 7
4.5 Terrain Data and Land Use 8
4.6 Meteorological Data 8
4.7 Receptor Grid 8
4.8 Background Data 9
4.9 In-Stack Ratio (NO2 to NOX Conversion) 9
5. SUMMARY OF MODELING RESULTS 10

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TABLES
Table 1. Comparison of Facility-Wide Potential Emissions to UDAQ Modeling Thresholds 2
Table 3. Applicable NAAQS Increment 4
Table 4. Modeling Output for NAAQS Compliance Demonstration 5
Table 5. Minimum Discrete Receptor Spacing 9
Table 6. NO2 NAAQS Results 10

ATTACHMENTS
Attachment A
Figures
Attachment B
Tables
Attachment C
UDAQ-Approved Modeling Protocol
Attachment D
Electronic Modeling Files

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1. INTRODUCTION
Ramboll Americas Engineering Solutions Inc. (Ramboll) is submitting this supplemental air dispersion
modeling report on behalf of eBay Inc. (the applicant) for the SLC Data Center1, which is proposing to
construct and operate six new emergency generators at the data center in South Jordan, Salt Lake
County, Utah (Attachment A, Figure A-1) which currently operates under DAQE-AN141800011-21.
This modeling report is intended to supplement the previously submitted NOI dated July 18, 2023, in
response to comments from UDAQ on stack heights for the generators.
Primary power to the facility is supplied by the local electrical utility. Secondary backup power is
currently provided by 29 emergency diesel generators located onsite, 26 of which are 1.5 megawatts
(MW) or greater in electrical standby power capacity, 1 of which is 1,000 kW, and 2 of which are less
than 100 kilowatts (kW) fire pump generators. As described in the application for an Approval Order
(AO) modification submitted simultaneously, eBay proposes to update the operational hours of two
diesel-fired emergency generators from 66 hours a year to 100 hours a year and reduce the
operational hours for twenty-nine (29) diesel-fired emergency generators from 66 hours a year to 60
hours a year. The applicant is also requesting to relocate two diesel-fired emergency backup
generators, remove two diesel-fired emergency generators from the permit, and remove the Bloom
Energy Servers at eBay’s SLC Data Center (facility) located in South Jordan, Salt Lake County, Utah.
Per the federal New Source Performance Standards (NSPS), 40 CFR 60 Subpart IIII – Stationary
Compression Ignition Internal Combustion Engines, each generator is restricted to a maximum of 100
hours per calendar year of operation for maintenance checks and readiness testing.2 Of that
allocation, each generator is also allowed up to 50 hours per calendar year of other non-emergency
operation.3
This modeling report describes the approach for modeling predicted compliance with the National
Ambient Air Quality Standards (NAAQS) for the 1-hour and annual nitrogen dioxide (NO2) standards,
in accordance with the Utah Division of Air Quality (UDAQ) guidance, Emissions Impact Assessment
Guidelines, and specific guidance given by UDAQ personnel.4,5

1 DAQE-AN141800010-19 lists the source name as “Topaz (South Jordan) Data Center”. eBay is requesting a source name change to “SLC Data Center” as part of this NOI.
2 40 CFR 60.4211(f)(2)
3 40 CFR 60.4211(f)(3)
4 Utah Division of Air Quality. New Source Review Section. 2013. Emissions Impact Assessment Guidelines. March. Available at: http://www.deq.utah.gov/Permits/air/docs/2013/03Mar/
EmissionsImpactAssessmentGuideline.pdf
5 Refer to Pre-NOI meeting held between eBay, Ramboll, and UDAQ on July 23, 2019.
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2. UTAH DAQ MODELING REQUIREMENTS
Pursuant to UDAQ’s Emissions Impact Assessment Guidelines6 and UAC Rule 307-4107, new sources,
or modifications to existing sources, with total controlled emission increases greater than listed
modeling thresholds8 are required to submit an air dispersion modeling analysis as part of a complete
Notice of Intent (NOI) application. A comparison of the facility-wide potential-to-emit (PTE) with
UDAQ’s modeling thresholds is provided in Table 1.
Table 1. Comparison of Facility-Wide Potential Emissions to UDAQ Modeling Thresholds
Pollutant
Facility-Wide Potential
Emissions(a)(b)
(tpy)
Emissions Levels to Require Modeling(c) (tpy)
Exceeds?
Nitrogen Dioxide (NO2) 45.55 40 Yes
Sulfur Dioxide (SO2) 0.056 40 No
Fugitive Emissions:
Particulate Matter Less than 10 Microns in Diameter (PM10)
-- 5 No
Non-Fugitive Emissions:
Particulate Matter Less than
10 Microns in Diameter (PM10)
2.94 15 No
Carbon Monoxide (CO) 6.68 100 No
Notes:
a) Pollutants emission rates are based on the maximum short-term emission rate of that pollutant provided
by the chosen engine vendor in the engine specification sheet. Additional detail on potential short-term
and annual emissions expected from the proposed facility will be discussed in the NOI.
b) Based on 100 operating hours per year for Fire Pump generators and G15 and G16, and 60 hours per year
for all other generators
c) Taken from UDAQ’s Emissions Impact Assessment Guidelines.

Per Table 1, the modeling thresholds for NO2 would be exceeded for the proposed Project, and
therefore UDAQ requires dispersion modeling for the annual NO2 NAAQS. Additionally, the applicant
understands that UDAQ would like the proposed facility to demonstrate compliance with the 1-hour
NO2 NAAQS since the proposed facility’s NOX emissions will potentially exceed 10 pounds per hour.9
Consistent with UDAQ’s Emissions Impact Assessment Guidelines, permitted facilities must evaluate
emissions of Hazardous Air Pollutants (HAPs) against UDAQ’s Emission Threshold Values (ETVs) for

6 Utah Division of Air Quality. New Source Review Section. 2024. Emissions Impact Assessment Guidelines. March. Available at: https://deq.utah.gov/air-quality/emissions-impact-assessment-guideline-preface
7 Utah Office of Administrative Rules. 2020. Rule 307-410. Permits: Emissions Impact Analysis. January. Available
at: https://rules.utah.gov/publicat/code/r307/r307-410.htm
8 Utah Office of Administrative Rules. 2020. Rule 307-410-4. Permits: Emissions Impact Analysis. Modeling of Criteria Pollutants in Attainment Areas. January. Available at: https://rules.utah.gov/publicat/code/r307/r307-
410.htm#E4
9 Refer to Pre-NOI meeting held between eBay, Ramboll, and UDAQ on July 23, 2019.
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each pollutant. However, since the engines are subject to NSPS IIII, they are exempt from R307-410-
5,10 as noted below:
“The requirements of R307-410-5 do not apply to installations which are subject to or are scheduled
to be subject to an emission standard promulgated under 42 U.S.C. 7412 at the time a notice of intent
is submitted, [unless the director determines the delay in the implementation of an emission standard
might post an unacceptable risk to public health]. This exemption does not affect requirements
otherwise applicable to the source, including requirements under R307-401.11”
10 Utah Office of Administrative Rules. 2020. R307-410-5. Permits: Emissions Impact Analysis. https://rules.utah.gov/publicat/code/r307/r307-410.htm
11 Utah Administrative Code. R307-401. Permit: New and Modified Sources. https://rules.utah.gov/publicat/code/r307/r307-401.htm
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3. AIR QUALITY ANALYSIS APPROACH
Air dispersion modeling analyses were completed to demonstrate that the proposed facility will not
cause or contribute to an exceedance of the annual or 1-hour NO2 NAAQS. The analyses were
conducted consistent with the following state and federal guidance documents:
• UDAQ. New Source Review Section. Emissions Impact Assessment Guidelines. (March 2013);
• U.S. EPA’s Guideline on Air Quality Models 40 CFR 51, Appendix W (Revised, January 17, 2017),
herein referred to as Appendix W;
• U.S. EPA’s AERMOD Implementation Guide (Revised, April 17, 2023);
• U.S. EPA’s New Source Review Workshop Manual (Draft, October 1990);
• U.S. EPA, Office of Air Quality Planning and Standards, Memorandum from Mr. Tyler Fox to
Regional Air Division Directors. Guidance Concerning the Implementation of the 1-hour NO2
NAAQS for the Prevention of Significant Deterioration Program (June 29, 2010); and
• U.S. EPA, Office of Air Quality Planning and Standards, Memorandum from Mr. Tyler Fox to
Regional Air Division Directors. Additional Clarification Regarding Application of Appendix W
Modeling Guidance for the 1-hour NO2 National Ambient Air Quality Standard (March 1, 2011).
The air quality assessment is generally performed in two phases: a Significance Analysis and a full
impact analysis of the NAAQS. Each of these analyses are discussed in more detail in the following
sections. The applicable values for the annual and 1-hour NO2 Significant Impact Level (SIL) and
NAAQS are provided in Table 2.
Table 2. Applicable NAAQS Increment
Pollutant Averaging Period
Class II
SIL
(µg/m3)
Primary NAAQS (µg/m3)
NO2 1-Hour 7.5 (a) 188 (b)
NO2 Annual 1.0 100 (c)
Notes:
a) U.S. EPA has not promulgated a 1-hour NO2 SIL. The interim SIL of 7.5
µg/m3 is based on U.S. EPA’s recommended value of 4% of the 1-hour NO2
NAAQS (4 ppb), per U.S. EPA, Office of Air Quality Planning and Standards,
Memorandum from Mr. Tyler Fox to Regional Air Division Directors.
Guidance Concerning the Implementation of the 1-hour NO2 NAAQS for the
Prevention of Significant Deterioration Program (June 29, 2010).
b) Standard of 100 ppb converted to µg/m3. 98th percentile of 1-hour daily
maximum concentrations, averaged over three years.
c) Standard of 53 ppb converted to µg/m3. Annual mean.

3.1 Significance Analysis
A Significance Analysis is required to determine whether the proposed project could cause a significant
impact on the area surrounding the facility. A significant impact occurs if ambient concentrations
exceed the SIL. If the highest modeled concentrations from the proposed emissions increase are less
than the SIL for all averaging periods, no further analysis is required for that pollutant. Otherwise, a full
impact analysis is required to demonstrate that the facility will not cause or contribute to an
exceedance of the NAAQS for that pollutant and averaging period.
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Ramboll anticipated that project impacts would be above the SIL for the 1-hr and Annual NO2 averaging
periods and thus did not conduct significance modeling and continued with a NAAQS analysis for all
required pollutants and averaging periods.
3.2 NAAQS Analysis
Per UDAQ Guidance, a NAAQS modeling evaluation includes the proposed sources at the project site
plus a regional inventory of nearby sources12 with NOX emissions potentially impacting the ambient air
concentrations of NO2 within the vicinity of the site. A representative background concentration is
then added to the modeled concentrations for comparison against the applicable NAAQS to represent
the contribution of sources not explicitly modeled. The model outputs that were used for assessing
compliance with the NAAQS are summarized in Table 3.
Table 3. Modeling Output for NAAQS Compliance Demonstration
Pollutant and Averaging Period Design Standard Model Output
1-Hour NO2
98th percentile of daily
maximum 1-hour
concentrations, averaged over
three years
Daily maximum 1-hour average of the 32nd high across 5 years, on a receptor-by-receptor basis (a)
Annual NO2 Annual Mean Maximum annual average
Notes:
(a) Typically, for sources that operate daily, the 8th high 1-hr average NO2 is compared to the NAAQS.
Similarly, for sources that operate one day per week, the model has the capability to input the sources for
only one day per week and the 8th high would then be compared to the NAAQS. However, as described in
Section 4.2, the proposed generator testing and maintenance would occur on a monthly and annual basis
and AERMOD is limited in its ability to model sources that operate at that frequency. Per UDAQ direction,13 to
scale to the appropriate ranked output, all sources were input to the model once per week and the 32nd high
was compared to the NAAQS.

Per input from UDAQ,14 three existing nearby sources with emissions in tons per year (Q) divided by
distance in kilometers (d) >10 were identified for possible inclusion in the cumulative analysis
(Attachment C). The inclusion of the nearby sources in the modeling depends on the modeled
concentrations from the Project (plus background) compared to the NAAQS. Per further input from
UDAQ, Ramboll would include the largest emitter of the three sources if Project-only (plus
background) impacts were greater than 85% of the NAAQS and would include all three sources if
Project-only (plus background) impacts were greater than 90% of the NAAQS, at the Point of
Maximum Impact (PMI).15 As discussed in Section 5, the Project-only (plus background) impacts were
much smaller than 85% of the NAAQS. Thus, the NAAQS analysis included the Project-specific impacts
plus the monitored background concentrations and no nearby sources were included.

12 Per UDAQ’s “Nearby Source Emission Inventory Request Form”, permit applicants can screen out sources that
are in the inventory but have small emissions by eliminating sources where Q/D <10, where Q is the emissions in TPY and D is the distance to the offsite source from the source being modeled, in kilometers.
13 Per email correspondence with Dave Prey on February 11, 2020.
14 Nearby source information was provided by Dave Prey (UDAQ) on May 23, 2019.
15 Per email correspondence with Dave Prey on June 28, 2019.
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4. MODELING METHODOLOGY, SETTINGS, AND INPUTS
This section outlines the technical approach used in the 1-hour and Annual NO2 modeling analysis.
Figures and tables supporting this modeling evaluation and outlining the model inputs are provided in
Attachments A and B, respectively. The approved modeling protocol for the project is provided in
Attachment C, and a CD-ROM with the electronic modeling files is included in Attachment D.
4.1 Model Selection and Settings
To estimate ambient concentrations of NO2, the applicant used the latest version of the AERMOD
modeling system (23132). AERMOD is U.S. EPA’s recommended air dispersion model for near-field
(within 50 kilometers [km]) modeling analyses. AERMOD is appropriate for use in estimating ground-
level ambient air concentrations resulting from non-reactive buoyant emissions from sources located
in simple and complex terrain.
Modeled impacts were estimated using AERMOD in conjunction with information about the site, the
proposed locations of the NOX-emitting stacks, representative meteorological data, and nearby
receptors. The North American Datum of 1983 (NAD83) of the Universal Transverse Mercator (UTM)
Coordinate System (Zone 12) was used, which provides a constant distance relationship anywhere on
the map or domain. The units of the coordinates are in meters.
4.1.1 NO2 Modeling Approach
The applicant used the Tier 3 Ozone Limiting Method (OLM Group) for the 1-hour NO2 NAAQS
analyses. As part of the recent Appendix W updates, U.S. EPA incorporated the OLM Group Method as
a regulatory option for NO2 modeling. In addition, the applicant requested and received pre-approval
from UDAQ air dispersion modeling staff for the use of Tier 3 model options.16 Background
concentrations and NO2/NOX in stack ratios are discussed in sections 4.8 and 4.9, respectively.
4.2 Modeled Sources and Release Parameters
The existing and proposed emergency standby generators and fire pumps will be the primary source
of NOX emissions at the proposed facility. The emissions from the engines will exhaust through vertical
stacks and were modeled as point sources using manufacturer-provided stack parameters
(Attachment B, Table B-1). Generators with a stack addition were modeled by adding the enclosure
as a building structure to account for downwash, and accounting for the additional height from the
stack addition.17
Short-term and annual emission rates were conservatively based on the manufacturer's "Not-to-
Exceed" emissions data for each generator at a load specified by the applicant. Annual average
emissions rates were conservatively based on operations at 100% load and were annualized according
to the allowable non-emergency operating time per year. A detailed derivation of the modeled NOX
emission rates is provided in Attachment B.

16 Approved by Dave Prey, UDAQ, via email on May 1, 2020.
17 Approved by Dave Prey, UDAQ, via email on August 16, 2024.
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Typical generator maintenance and readiness testing18 would include three types of operations, all of
which would occur between the hours of 8:00 AM and 6:00 PM:
1. monthly tests including groupings of 2 to 4 generators19 operating simultaneously and lasting no
longer than 30 minutes,
2. annual tests of single generators lasting no longer than one hour, and
3. annual operational verification of single generators operating with no load and lasting no longer
than 5 minutes.
For the 1-hour NO2 NAAQS analyses, two modeling analyses were carried out to determine the worst-
case combination of the monthly and annual tests described above. First, the monthly tests (item 1 in
the above list) were modeled for each generator grouping to determine the worst-case monthly test
generator group. Second, the worst-case generator groupings determined from the previous step were
modeled along with each annual test (item 2 in the list above) to determine the worst-case pair of
monthly and annual tests. Per communications with UDAQ, the 5 minute, no load operational
verification (item 3 in the above list) was not included in the modeling as these verifications would
have very little impact on the ambient 1-hr average NO2 concentrations.20 For the Annual NO2 NAAQS
analysis, all existing and proposed generators were modeled simultaneously between the hours of
8:00 AM and 6:00 PM for maintenance and readiness testing. Non-emergency operation of the
generators would be conducted in accordance with the operational limitations used in the modeling to
achieve a passing scenario for the 1-hour and Annual NO2 NAAQS, using the inputs and emission rates
discussed above. Emergency operations are not regulated by UDAQ and, as such, are not included in
the model or subject to operational limitations.
A list of the generator IDs included in each OLM group for the NO2 modeling is included in
Attachment B, Table B-2. Individual source groups were modeled in separate runs due to
limitations of the OLM Group Method which does not allow sources to be included in multiple OLM
Groups.
4.3 Building Downwash
The AERMOD model incorporates Plume Rise Modeling Enhancements (PRIME) to account for
downwash. The direction-specific building downwash dimensions used as inputs were determined by
the latest version (04274) of the Building Profile Input Program, PRIME (BPIP PRIME). BPIP PRIME
uses building downwash algorithms incorporated into AERMOD to account for the plume dispersion
effects of the aerodynamic wakes and eddies produced by buildings and structures.
The applicant evaluated on-site buildings and water storage tanks at the facility for downwash effects
on each modeled point source. Since the on-site buildings will have multi-tiered roofs, the tiered
sections were treated as separate buildings for this modeling demonstration. The modeled
parameters for the buildings and the water storage tanks are provided in Attachment B, Table B-3.
4.4 Good Engineering Practice Stack Height Analysis
U.S. EPA has promulgated regulations that limit the maximum stack height that may be used in a
modeling analysis to no more than the Good Engineering Practice (GEP) stack height. The purpose of
this requirement is to prevent the use of excessively tall stacks to reduce the modeled concentrations
of a pollutant. GEP stack height is a function of the heights of nearby structures. In general, the
18 Emergency operation is not limited.
19 Monthly testing of generators G1-G7 would occur 4 at a time while monthly testing of all other generators may
occur 2 at a time.
20 Per email correspondence with Dave Prey on February 12, 2020.
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maximum value for GEP stack height is 65 meters. The height of the proposed generator stacks will
not exceed the GEP stack height.
4.5 Terrain Data and Land Use
Per U.S. EPA guidance, terrain elevations were incorporated into the model using the most recent
version (18081) of AERMAP, AERMOD’s terrain preprocessor. Terrain elevation data for the entire
modeling domain was extracted from 1/3 arc-second National Elevation Data (NED) files with a
resolution of approximately 10 meters. The NED files were obtained from the United States Geological
Survey (USGS) Multi-Resolution Land Characteristics Consortium (MRLC).21 AERMAP was configured
to assign elevations for the sources, buildings, property line receptors, and discrete gridded receptors
in the modeling domain.
Land use classification determines the type of area to be modeled. The different classifications, urban
or rural, incorporate distinct pollutant dispersion characteristics and affect the estimation of downwind
concentrations when used in the model. Based on the land use around the facility, the urban
boundary layer option in the model was not selected.
4.6 Meteorological Data
AERMOD requires a meteorological input file to characterize the transport and dispersion of pollutants
in the atmosphere. Surface and upper air meteorological data inputs, as well as surface parameter
data describing the land use and surface characteristics near the site, are processed using AERMET,
the meteorological preprocessor to AERMOD. The output file generated by AERMET is the
meteorological input file required by AERMOD.
A pre-processed surface and upper air meteorological data set for the Salt Lake City airport was
provided by UDAQ for this modeling assessment for five meteorological years (2008-2012).22
4.7 Receptor Grid
Ground-level concentrations were calculated at receptors placed along the facility fence line and on a
circular, Cartesian grid. The approximate property boundary and fence line are illustrated in
Attachment A, Figure A2. Ground level receptors were placed along the fence line at approximately
10-meter intervals, resulting in 201 fence line receptors. Beyond the fence line, a variable density,
discrete Cartesian receptor grid was used for the modeling assessment, as outlined in Table 4. This
discrete receptor grid generated 9,470 receptors.23

21 http://www.mrlc.gov
22 Meteorological data for Salt Lake City Airport for 2008 through 2012 provided by Dave Prey, UDAQ on May 1,
2019.
23 The receptor grid was described in the modeling protocol and approved by Dave Prey, UDAQ on May 1, 2020. The receptor grid meets the criteria described in section VIII.a of the UDAQ Emissions Impact Assessment
Guidelines. https://deq.utah.gov/legacy/permits/air-quality/docs/2013/03Mar/EmissionsImpactAssessmentGuideline.pdf
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Table 4. Minimum Discrete Receptor Spacing
Distance from Fence Line Receptor Spacing
Along fence line 10 meters
0 – 250 meters 25 meters
250 – 1000 meters 50 meters
1,000 – 3,000 meters 100 meters
3,000 – 6,000 meters 200 meters
6,000 – 12,000 meters 500 meters

4.8 Background Data
Consistent with Section 4.1.1 of this Report, UDAQ has provided pre-approval for the use of Tier 3
model options for NO2 modeling. The NO2 and O3 background data used in this modeling exercise
(Attachment B, Table B-4) were developed from hourly data from the Air Quality System (AQS)
Data Mart database for the Herriman station (AQS ID: 49-035-3013) for the most recent three-year
period of available data (January 2016 through December 2018). The three-year period data were
averaged for use as the Annual NO2 background concentration. Background concentrations of 1-hr NO2
and O3 were calculated using the three-year average of the 3rd highest of the available monitoring
data, determined by accounting for both season and hour-of-day.24
4.9 In-Stack Ratio (NO2 to NOX Conversion)
Consistent with the approved modeling protocol, the applicant used a NO2/NOX in stack ratio of 0.10 for
the proposed emergency generators. This value was selected based on data obtained from the U.S.
EPA’s In-Stack Ratio Database for diesel/kerosene-fired reciprocating internal combustion engines
(RICE). The U.S. EPA database has data for 57 diesel-fired RICE that indicate a median, mean, and
even a second-high value, that are less than a 0.10 NO2/NOX ratio.

24 https://www.epa.gov/sites/production/files/2015-07/documents/appwno2_2.pdf
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5. SUMMARY OF MODELING RESULTS
Modeling was conducted to demonstrate compliance with the 1-hour NO2 and Annual NAAQS. The
results of the analysis are presented in Table 5 and demonstrate that there are no predicted
violations of the NAAQS. Isopleth depictions of the results for the 1-hour and Annual NO2 NAAQS
analysis are presented in Attachment A, Figures A-3 and A-4.
Table 5. NO2 NAAQS Results
Averaging Period Year UTM East (m) UTM North (m)
Maximum Modeled Ambient Conc. (µg/m3)
NAAQS (µg/m3) Above NAAQS?
Annual 2008-2012 411106.98 4491068.72 15.3 100 No
1-Hour 2008-2012 411286.98 4491068.96 106.28(a) 188 No
Notes:
(a) The value includes background concentrations discussed in section 4.8. Consistent with section 3.2 of this Report, no offsite sources were modeled.
The modeled 1-hour NO2 concentration shown in Table 5 is representative of the maximum value
from all the modeled OLM groups, in the form of the NAAQS. A full summary of the model results for
the 1-hour NO2 NAAQS analysis, including the modeled concentrations for each OLM group included in
the 1-hour NO2 modeling, is provided in Attachment B, Table B-2.

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ATTACHMENT A
FIGURES
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ATTACHMENT B
TABLES
X (m) Y (m)Engine Load (kWe)
Stack Release Temperature (K)
Stack Release Velocity (m/s)
Hourly Average Stack Emission
Engine Load (kWe)
Stack Release Temperature (K)
Stack Release Velocity (m/s)Stack Emission Rate (g/s)Engine Load (kWe)
Stack Release Temperature (K)
Stack Release Velocity (m/s)
Stack Emission
Rate (g/s)4
FP1 CAT00c44ed4b01369 Caterpillar D100-6 Generator Set 100 KW 156 hp SLC01 1 at a time 100 411232.2 4490852.7 1550.7 0.13 2.5 Flapped Rain Cap 0 (Quarterly) -- -- -- 100.00 -- -- -- 100 779.26 26.31 0.0011G0122171-05 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411343.2 4490965.7 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0222171-01 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411331.2 4490965.9 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0322171-02 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411319.4 4490966.2 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0422171-03 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411307.8 4490966.2 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0522171-06 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411295.4 4490966.2 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0622171-04 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411283.5 4490966.2 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G0722171-07 SLC01 Detroit Diesel 20V4000G83L 3D 3250kW, 4358 hp SLC01 60 411271.9 4490966.2 1550.7 0.71 6.1 Flapped Rain Cap 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.14G08WYB01214 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411325.9 4490763.3 1550.7 0.61 5.8 Unrestricted 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15G09WYB01747 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411384.2 4490811.6 1550.7 0.61 7.0 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15
G10 WYB01742 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411195.0 4490755.3 1550.7 0.61 6.9 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15
G11 WYB01746 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411383.2 4490795.9 1550.7 0.61 7.0 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15
G12 WYB01741 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411383.2 4490802.0 1550.7 0.61 7.0 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15
G13 WYB01732 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411383.5 4490821.7 1550.7 0.61 6.9 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15G14WYB01738 Caterpillar C175-16 3000kW, 4423 hp SLC02 1 at a time 60 411383.5 4490828.0 1550.7 0.61 6.8 Flapped Rain Cap 1,000 721.63 22.01 0.787 2,500 740.19 35.06 7.103 3,100 750.87 41.43 0.15G24LYM00235 Caterpillar 3516C Generator Sets 2500kW, 3634 hp SLC02 Reconfig 60 411314.9 4490726.4 1550.7 0.46 6.4 Flapped Rain Cap 650 621.38 22.02 0.639 1,750 671.04 42.25 3.709 2,500 727.98 54.07 0.11G25LYM00241 Caterpillar 3516C Generator Sets 2500kW, 3634 hp SLC02 Reconfig 60 411320.7 4490726.4 1550.7 0.46 6.4 Flapped Rain Cap 650 621.38 22.02 0.639 1,750 671.04 42.25 3.709 2,500 727.98 54.07 0.11G26LY500179 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P3 60 411130.1 4490957.6 1550.7 0.46 8.0 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G27LY500180 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P3 60 411130.4 4490950.7 1550.7 0.46 8.0 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088FP2PE4045N005437 John Deere engine 86 hp SLC03 P1 1 at a time 100 411102.4 4490830.2 1555.5 0.13 9.4 Unrestricted ----------------64 744.26 17.18 8.3E-04G15CAT3516CJSBJ02058 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 100 411130.4 4490924.1 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.061G16CAT3516CVSBJ02056 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 100 411130.5 4490917.8 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.061
G17 CAT3512CALYH00157 Caterpillar 3512C Generator Sets 1500kW, 2206 hp SLC03 P1 1 at a time 60 411130.8 4490911.3 1555.5 0.46 7.6 Flapped Rain Cap 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 0.066
G18 CAT3512CVLYH00156 Caterpillar 3512C Generator Sets 1500kW, 2206 hp SLC03 P1 1 at a time 60 411130.7 4490904.9 1555.5 0.46 7.6 Flapped Rain Cap 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 0.066
G19 CAT3516CCSBJ02061 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 60 411130.3 4490898.5 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088
G20 CAT3516CVSBJ02057 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 60 411130.3 4490892.1 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G21CAT3516CLSBJ02063 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 60 411130.3 4490885.6 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G22CAT3516CASBJ02059 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P1 60 411130.3 4490879.2 1555.5 0.46 7.6 Flapped Rain Cap 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G23CAT00C32VJSJ03296 Caterpillar C32 Generator Set 1000kW, 1474 hp SLC03 P1 1 at a time 60 411130.8 4490872.8 1555.5 0.36 7.1 Flapped Rain Cap 300 631.32 15.39 0.344 700 705.37 30.39 1.324 1,000 749.54 38.33 0.040G28LY500394 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P2 60 411130.4 4490970.7 1555.5 0.46 7.6 Vertical 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G29LY500398 Caterpillar 3516C Generator Sets 2000kW, 2937 hp SLC03 P2 60 411130.4 4490964.1 1555.5 0.46 7.6 Vertical 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.088G322A300914 Caterpillar , 750 kW Nominal Site rating SLC03 P3 1 at a time 60 411130.8 4490944.0 1555.5 0.25 6.9 Flapped Rain Cap 250 657.48 23.56 0.273 600 763.54 44.92 1.165 750 780.76 51.44 0.031G332A300761 Caterpillar , 750 kW Nominal Site rating SLC03 P2 1 at a time 60 411130.8 4490937.2 1555.5 0.25 6.9 Vertical 250 657.48 23.56 0.273 600 763.54 44.92 1.165 750 780.76 51.44 0.031
Notes1
2
3
4
Coordinates are based on NAD 1983 datum Zone 12N.Monthly generator testing of of generators G1-G7 occur 4 generators at a time while other generators occur 2 or 1 at a time. Monthly tests for all non-fire-pump engines occur for 30 minutes at a time at the engine load specified in this Table (30% load). Annual tests of all non-fire-pump generators are modeled one at a time for a full hour at the engine load specified in this Table. All monthly and annual tests would occur between 8 a.m. and 6 p.m. Fire pump engines were not included in 1-hr NO2 modeling since emissions from these engines are small and they are unlikely to be tested simultaneously with other generators.
Annual average NO2 modeling will include all generators and parameters assuming 100% load. The emission rates are annualized assuming 100 hours per year for the fire pumps and G15-G16, and 60 hours per year for all other generators, as specified in the NOI.
Generator1
Groups of 4 at a time
2 at a time
2 at a time
2 at a time
2 at a time
2 at a time
Description Hours/year
Coordinates2
Elevation (m)
Generator locations and release heights and stack diameters were provided by eBay. Emission rates, exhaust temperature and release velocity were retrieved from engine manufacturer spec sheets. The Generator ID matches the IDs in the NOI application and proposed facility configuration after the proposed generator relocations.
2 at a time
Stack Diameter (m)
Stack Release Height (m)2 Release Type
Table B1
Air Model Input Parameters
eBay Data Center
South Jordan, Utah
Monthly Test Parameters3 Annual Test Parameters3
1-hr NO2 Model Inputs Annual NO2 Model Inputs
100% Engine Load (Annualized)
Building Monthly Testing NotesSerial Number
# Confidential
X Y
M103A101 Monthly GRP103 & Annual SLC1_G01 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC1_G01 85.84 411275.00 4491075.00
M103A102 Monthly GRP103 & Annual SLC1_G02 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC1_G02 87.18 411266.98 4491068.94
M103A107 Monthly GRP103 & Annual SLC1_G07 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC1_G07 89.75 411437.35 4490655.96
M103A208 Monthly GRP103 & Annual SLC2_G08 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G08 101.52 411286.98 4491068.96
M103A209 Monthly GRP103 & Annual SLC2_G09 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G09 102.54 411286.98 4491068.96
M103A210 Monthly GRP103 & Annual SLC2_G10 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G10 86.02 411218.75 4490633.59
M103A211 Monthly GRP103 & Annual SLC2_G11 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G11 101.23 411286.98 4491068.96
M103A212 Monthly GRP103 & Annual SLC2_G12 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G12 101.86 411286.98 4491068.96
M103A213 Monthly GRP103 & Annual SLC2_G13 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G13 106.28 411286.98 4491068.96
M103A214 Monthly GRP103 & Annual SLC2_G14 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G14 104.21 411286.98 4491068.96
M103A224 Monthly GRP103 & Annual SLC2_G24 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G24 84.50 411226.98 4491068.88
M103A225 Monthly GRP103 & Annual SLC2_G25 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G25 83.33 411378.22 4490645.86
M103A226 Monthly GRP103 & Annual SLC2_G26 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G26 83.29 411547.88 4491068.32
M103A227 Monthly GRP103 & Annual SLC2_G27 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC2_G27 83.29 411547.88 4491068.32
M103A315 Monthly GRP103 & Annual SLC3_G15 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G15 83.29 411096.98 4491068.71
M103A316 Monthly GRP103 & Annual SLC3_G16 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G16 83.31 411096.98 4491068.71
M103A317 Monthly GRP103 & Annual SLC3_G17 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G17 83.29 411417.74 4490652.02
M103A318 Monthly GRP103 & Annual SLC3_G18 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G18 83.29 411036.98 4491068.62
M103A319 Monthly GRP103 & Annual SLC3_G19 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G19 83.83 411096.98 4491068.71
M103A320 Monthly GRP103 & Annual SLC3_G20 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G20 83.75 411106.98 4491068.72
M103A321 Monthly GRP103 & Annual SLC3_G21 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G21 83.32 411086.98 4491068.69
M103A322 Monthly GRP103 & Annual SLC3_G22 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G22 83.29 410996.98 4491068.57
M103A323 Monthly GRP103 & Annual SLC3_G23 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G23 83.29 411250.00 4491100.00
M103A328 Monthly GRP103 & Annual SLC3_G28 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G28 83.29 411075.00 4491100.00
M103A329 Monthly GRP103 & Annual SLC3_G29 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G29 83.29 411075.00 4491100.00
M103A332 Monthly GRP103 & Annual SLC3_G32 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G32 83.29 411417.74 4490652.02
M103A333 Monthly GRP103 & Annual SLC3_G33 SLC1_G03 SLC1_G04 SLC1_G05 SLC1_G06 SLC3_G33 83.29 411417.74 4490652.02
Notes:
Maximum modeled concentrations were modeled for each combination of annual generator test and the worst-case monthly generator test group.
Table B2
Maximum 1-hour NO2 Concentration at Point of Maximum Impact1
eBay Data CenterSouth Jordan, Utah
Source Group Description Source IDs
Maximum
Concentration
(ug/m3)
UTM Zone 12N
Coordinates
(m)
# Confidential
X YSLC01_CT01 Cooling Tower associated with Building 1 411,202.46 4,490,933.25 1,550.67 14.33 4SLC01_CT02 Cooling Tower associated with Building 2 411,201.90 4,490,916.37 1,550.67 14.33 4SLC01_CT03 Cooling Tower associated with Building 3 411,206.59 4,490,885.35 1,550.67 14.33 4SLC01_CT04 Cooling Tower associated with Building 4 411,206.43 4,490,868.52 1,550.67 14.33 4SLC01_FPG01 Enclosure for Fire Pump SLC1_FP1 411,232.19 4,490,852.68 1,550.67 2.18 4SLC01_GE01 Enclosure for SLC1_G01 411,271.93 4,490,967.25 1,550.67 4.67 4SLC01_GE02 Enclosure for SLC1_G02 411,283.50 4,490,967.25 1,550.67 4.67 4SLC01_GE03 Enclosure for SLC1_G03 411,295.39 4,490,967.25 1,550.67 4.67 4
SLC01_GE04 Enclosure for SLC1_G04 411,307.75 4,490,967.25 1,550.67 4.67 4SLC01_GE05 Enclosure for SLC1_G05 411,319.43 4,490,967.25 1,550.67 4.67 4SLC01_GE06 Enclosure for SLC1_G06 411,331.19 4,490,967.00 1,550.67 4.67 4SLC01_GE07 Enclosure for SLC1_G07 411,343.24 4,490,966.75 1,550.67 4.67 4SLC01_TANK Water Tank 411,202.87 4,490,963.74 1,550.67 3.35 36SLC01AMain Building 2 411,300.89 4,490,895.60 1,550.67 13.72 6SLC01BEast Tier Building 1 411,360.41 4,490,889.21 1,550.67 6.71 8SLC01CSoutheast Tier A Building 1 411,381.00 4,490,853.54 1,550.67 13.41 9SLC01DSoutheast Tier B Building 1 411,365.26 4,490,848.47 1,550.67 16.16 4SLC01ESouth Tier Building 1 411,300.97 4,490,848.52 1,550.67 16.16 7SLC01FWest Tier Building 1 411,246.14 4,490,885.94 1,550.67 6.71 4SLC02_GE09A Enclosure for SLC2_G09 411,207.80 4,490,750.50 1,550.67 5.18 4SLC02_GE10A Enclosure for SLC2_G10 411,195.04 4,490,760.36 1,550.67 5.18 4SLC02_GE11 Enclosure for SLC2_G11 411,377.19 4,490,795.85 1,550.67 4.88 4SLC02_GE12 Enclosure for SLC2_G12 411,377.23 4,490,801.96 1,550.67 4.88 4SLC02_GE13 Enclosure for SLC2_G13 411,377.48 4,490,821.71 1,550.67 4.88 4SLC02_GE14 Enclosure for SLC2_G14 411,377.48 4,490,827.99 1,550.67 4.88 4SLC02_GE24 Enclosure for SLC2_G24 411,314.88 4,490,726.40 1,550.67 4.88 4
SLC02_GE25 Enclosure for SLC2_G25 411,320.72 4,490,726.37 1,550.67 4.88 4SLC02_GE26 Enclosure for SLC2_G26 411,326.41 4,490,726.82 1,550.67 4.27 4SLC02_GE27 Enclosure for SLC2_G27 411,331.85 4,490,726.79 1,550.67 4.27 4SLC02_X00 Structures associated with Building 2 411,202.60 4,490,764.84 1,550.67 4.57 4SLC02_X01 Structures associated with Building 3 411,206.35 4,490,809.24 1,550.67 6.40 4SLC02_X02 Structures associated with Building 4 411,220.62 4,490,809.21 1,550.67 6.40 4SLC02_X03 Structures associated with Building 5 411,234.63 4,490,809.17 1,550.67 6.40 4SLC02_X04 Structures associated with Building 6 411,243.35 4,490,809.17 1,550.67 6.40 4SLC02_X05 Structures associated with Building 7 411,255.14 4,490,807.24 1,550.67 6.40 4SLC02_X06 Structures associated with Building 8 411,270.58 4,490,808.99 1,550.67 6.40 4SLC02_X07 Structures associated with Building 9 411,285.99 4,490,808.99 1,550.67 6.40 4SLC02AMain Building 2 411,317.50 4,490,799.50 1,550.67 13.72 14SLC02BSouth Tier Building 2 411,319.41 4,490,759.05 1,550.67 8.23 4SLC02CWest Tier Building 2 411,248.81 4,490,793.84 1,550.67 7.01 10SLC03_GE15A Tier 1 Enclosure for SLC1_G15 411,122.22 4,490,924.11 1,555.51 4.88 4SLC03_GE15B Tier 2 Enclosure for SLC1_G15 411,130.45 4,490,924.12 1,555.51 7.6 4SLC03_GE16A Tier 1 Enclosure for SLC1_G16 411,122.26 4,490,917.79 1,555.51 4.88 4SLC03_GE16B Tier 2 Enclosure for SLC1_G16 411,130.48 4,490,917.79 1,555.51 7.6 4SLC03_GE17A Tier 1 Enclosure for SLC1_G17 411,123.95 4,490,911.26 1,555.51 4.27 4SLC03_GE17B Tier 2 Enclosure for SLC1_G17 411,130.80 4,490,911.25 1,555.51 7.6 4SLC03_GE18A Tier 1 Enclosure for SLC1_G18 411,123.90 4,490,904.93 1,555.51 4.27 4SLC03_GE18B Tier 2 Enclosure for SLC1_G18 411,130.75 4,490,904.90 1,555.51 7.6 4SLC03_GE19A Tier 1 Enclosure for SLC1_G19 411,122.13 4,490,898.51 1,555.51 4.88 4SLC03_GE19B Tier 2 Enclosure for SLC1_G19 411,130.35 4,490,898.51 1,555.51 7.6 4SLC03_GE20A Tier 1 Enclosure for SLC1_G20 411,122.10 4,490,892.08 1,555.51 4.88 4
SLC03_GE20B Tier 2 Enclosure for SLC1_G20 411,130.32 4,490,892.09 1,555.51 7.6 4SLC03_GE21A Tier 1 Enclosure for SLC1_G21 411,122.07 4,490,885.62 1,555.51 4.88 4SLC03_GE21B Tier 2 Enclosure for SLC1_G21 411,130.28 4,490,885.62 1,555.51 7.6 4SLC03_GE22A Tier 1 Enclosure for SLC1_G22 411,122.05 4,490,879.19 1,555.51 4.88 4SLC03_GE22B Tier 2 Enclosure for SLC1_G22 411,130.28 4,490,879.20 1,555.51 7.6 4SLC03_GE23A Tier 1 Enclosure for SLC1_G23 411,123.94 4,490,872.83 1,555.51 4.27 4SLC03_GE23B Tier 2 Enclosure for SLC1_G23 411,130.77 4,490,872.82 1,555.51 7.1 4SLC03_GE26A Tier 1 Enclosure for SLC1_G26 411,122.18 4,490,957.33 1,555.51 4.88 4SLC03_GE26B Tier 2 Enclosure for SLC1_G26 411,130.41 4,490,957.34 1,555.51 8.0 4SLC03_GE27A Tier 1 Enclosure for SLC1_G27 411,122.22 4,490,950.72 1,555.51 4.88 4SLC03_GE27B Tier 2 Enclosure for SLC1_G27 411,130.44 4,490,950.71 1,555.51 8.0 4SLC03_GE28A Tier 1 Enclosure for SLC1_G28 411,122.18 4,490,970.68 1,555.51 4.88 4SLC03_GE28B Tier 2 Enclosure for SLC1_G28 411,130.40 4,490,970.69 1,555.51 7.6 4SLC03_GE29A Tier 1 Enclosure for SLC1_G29 411,122.18 4,490,964.06 1,555.51 4.88 4SLC03_GE29B Tier 2 Enclosure for SLC1_G29 411,130.40 4,490,964.07 1,555.51 7.6 4SLC03_GE32A Tier 1 Enclosure for SLC1_G32 411,123.97 4,490,943.95 1,555.51 4.27 4SLC03_GE32B Tier 2 Enclosure for SLC1_G32 411,130.82 4,490,943.95 1,555.51 6.9 4SLC03_GE33A Tier 1 Enclosure for SLC1_G33 411,123.95 4,490,937.15 1,555.51 4.27 4
SLC03_GE33B Tier 2 Enclosure for SLC1_G33 411,130.80 4,490,937.15 1,555.51 6.9 4SLC03_TANK Water Tank 411,124.39 4,490,980.77 1,555.51 3.35 36SLC03AMain Building 3 North 411,061.41 4,490,899.99 1,555.51 9.14 9SLC03E_AHU01 Building 3 Air Handling Unit East 411,105.23 4,490,873.24 1,555.51 6.04 4SLC03E_AHU02 Building 3 Air Handling Unit East 411,105.23 4,490,880.21 1,555.51 6.04 4SLC03E_AHU03 Building 3 Air Handling Unit East 411,105.15 4,490,893.39 1,555.51 6.04 4SLC03E_AHU04 Building 3 Air Handling Unit East 411,105.15 4,490,900.37 1,555.51 6.04 4SLC03E_AHU05 Building 3 Air Handling Unit East 411,105.32 4,490,913.53 1,555.51 6.04 4SLC03E_AHU06 Building 3 Air Handling Unit East 411,105.32 4,490,920.50 1,555.51 6.04 4SLC03E_AHU07 Building 3 Air Handling Unit East 411,105.23 4,490,933.67 1,555.51 6.04 4SLC03E_AHU08 Building 3 Air Handling Unit East 411,105.23 4,490,940.64 1,555.51 6.04 4SLC03E_AHU09 Building 3 Air Handling Unit East 411,105.23 4,490,953.81 1,555.51 6.04 4SLC03E_AHU10 Building 3 Air Handling Unit East 411,105.23 4,490,960.78 1,555.51 6.04 4SLC03E_AHU11 Building 3 Air Handling Unit East 411,105.32 4,490,973.86 1,555.51 6.04 4SLC03E_AHU12 Building 3 Air Handling Unit East 411,105.32 4,490,980.83 1,555.51 6.04 4SLC03W_AHU01 Building 3 Air Handling Unit West 411,017.59 4,490,873.26 1,555.51 6.04 4SLC03W_AHU02 Building 3 Air Handling Unit West 411,017.59 4,490,880.23 1,555.51 6.04 4SLC03W_AHU03 Building 3 Air Handling Unit West 411,017.52 4,490,893.34 1,555.51 6.04 4SLC03W_AHU04 Building 3 Air Handling Unit West 411,017.59 4,490,900.47 1,555.51 6.04 4SLC03W_AHU05 Building 3 Air Handling Unit West 411,017.52 4,490,913.45 1,555.51 6.04 4SLC03W_AHU06 Building 3 Air Handling Unit West 411,017.59 4,490,920.58 1,555.51 6.04 4
Vertices
Table B3Polygon Building Parameters for Proposed FacilityeBay Data CenterSouth Jordan, Utah
Model ID Description
UTM Zone 12N
Centroid Coordinates
(m)
Elevation
(m)
Height
(m)
# Confidential
Winter Spring Summer Fall
1 37.0 12.0 12.3 18.3
2 34.0 12.3 9.3 14.3
3 31.7 11.3 11.3 14.0
4 35.0 12.3 10.7 14.7
5 34.0 13.0 10.0 19.7
6 31.7 15.3 14.7 17.7
7 34.3 18.3 14.3 23.0
8 35.3 20.0 16.3 24.3
9 32.0 15.0 12.3 23.7
10 27.7 11.7 8.0 19.3
11 27.7 9.7 7.0 17.0
12 28.0 7.3 5.7 15.3
13 29.0 5.3 3.7 16.3
14 28.7 6.0 3.3 16.7
15 34.0 6.3 3.3 16.3
16 35.0 7.7 3.0 17.3
17 40.0 7.3 3.7 25.7
18 44.3 9.3 4.3 28.0
19 44.3 11.3 5.0 27.3
20 43.3 11.7 8.0 25.3
21 39.7 11.0 8.3 25.0
22 42.3 10.3 10.0 21.7
23 38.7 10.7 12.7 21.3
24 38.3 10.7 12.3 18.7
Notes:
1 NO2 background concentrations are in parts per billion (ppb) and are based on
hourly NO2 data from the Air Quality System Data Mart database for the Herriman
station (AQD ID: 49-035-3013) for the three-year period from January 2016 through
December 2018.
Table B4
1-hour NO2 Season by Hour Background Concentrations
eBay Data Center
South Jordan, Utah
Hour of Day Background NO2 Concentration (ppb)1
# Confidential
Air Dispersion Modeling Report
eBay SLC Data Center
Ramboll
Confidential
ATTACHMENT C
UDAQ-APPROVED MODELING PROTOCOL

Intended for
Utah Division for Air Quality

Prepared for
eBay
South Jordan, Utah

Prepared by
Ramboll US Corporation
Salt Lake City, UT

Project Number
1690013291

Date
April 2020

AIR DISPERSION
MODELING PROTOCOL

EBAY SLC DATA CENTER

Ramboll 50 West Broadway, Suite 300 Salt Lake City, UT 84101 USA T [phone] www.ramboll.com
CONTENTS
1. INTRODUCTION 1
2. UTAH DAQ MODELING REQUIREMENTS 2
3. MODELING METHODOLOGY, SETTINGS, AND INPUTS 3
3.1 Model Selection and Settings 3
3.2 Source Emission Rates and Operational Restrictions 3
3.3 Modeled Sources and Release Parameters 4
3.4 Building Downwash 4
3.5 Good Engineering Practice Stack Height Analysis 4
3.6 Receptor Grid 4
3.7 Terrain Data and Land Use 4
3.8 Meteorological Data 5
3.9 Background Data 5
3.10 In-Stack Ratio (NO2 to NOX Conversion) 5
3.11 Nearby Sources 5
4. MODELED IMPACTS ANALYSIS 7
TABLES
Table 1. Comparison of Facility-Wide Potential Emissions to UDAQ Modeling Thresholds 2 Table 2. Minimum Discrete Receptor Spacing 4 Table 3. Applicable NAAQS 7
APPENDICES
Appendix A: Figures
Appendix B: Source Parameters
Air Dispersion Modeling Protocol
Introduction
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1. INTRODUCTION
Ramboll US Corporation (Ramboll) is submitting this air dispersion modeling protocol on behalf of eBay Inc. (the applicant) for the West Jordan Data Center, which is proposing to construct and operate six new emergency generators at the data center in South Jordan, Salt Lake County, Utah which currently operates under DAQE-AN141800010-19 (Appendix A).
Primary power to the facility is supplied by the local electrical utility. Secondary backup power is currently provided by 29 emergency diesel generators located onsite, 26 of which are 1.5 megawatts (MW) or greater in electrical standby power capacity, 1 of which is 1,000 kW, and 2 of which are less than 100 kilowatts (kW) fire pump generators. eBay is proposing to add 6 new emergency diesel generators, 4 of which are 2 MW in electrical standby power capacity, and 2 of which are 750 kW in electrical standby power capacity. Per the federal New Source Performance Standards (NSPS), 40
CFR 60 Subpart IIII – Stationary Compression Ignition Internal Combustion Engines, each generator is restricted to a maximum of 100 hours per calendar year of operation for maintenance checks and readiness testing.0F1 Of that allocation, each generator is also allowed up to 50 hours per calendar year of other non-emergency operation.1F2
This modeling protocol describes the approach for modeling predicted compliance with the National Ambient Air Quality Standards (NAAQS) for the 1-hour and annual nitrogen dioxide (NO2) standards, in accordance with the Utah Division of Air Quality (UDAQ) guidance, Emissions Impact Assessment Guidelines, and specific guidance given by UDAQ personnel.2F3,3F4

1 40 CFR 60.4211(f)(2)
2 40 CFR 60.4211(f)(3)
3 Utah Division of Air Quality. New Source Review Section. 2013. Emissions Impact Assessment Guidelines. March. Available at: http://www.deq.utah.gov/Permits/air/docs/2013/03Mar/ EmissionsImpactAssessmentGuideline.pdf
4 Refer to Pre-NOI meeting held between eBay, Ramboll, and UDAQ on July 23, 2019.
Air Dispersion Modeling Protocol
UDAQ Modeling Requirements
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2. UDAQ MODELING REQUIREMENTS
Pursuant to UDAQ’s Emissions Impact Assessment Guidelines4F5 and UAC Rule 307-4105F6, new sources with total controlled emission increases greater than the modeling thresholds are required to submit an air dispersion modeling analysis as part of a complete Notice of Intent (NOI) application. A comparison of the facility-wide potential-to-emit (PTE) with UDAQ’s modeling thresholds is provided in Table 1.
Table 1. Comparison of Facility-Wide Potential Emissions to UDAQ Modeling Thresholds
Pollutant
Facility-Wide Potential Emissions1,2 (tpy)
Emissions
Levels to
Require
Modeling3
(tpy)
Exceeds?
Nitrogen Dioxide (NO2) 56 40 Yes
Sulfur Dioxide (SO2) 0.05 40 No
Fugitive Emissions: Particulate Matter Less than 10 Microns in Diameter (PM10) -- 5 No
Non-Fugitive Emissions: Particulate Matter Less than 10 Microns in Diameter (PM10) 2.9 15 No
Carbon Monoxide (CO) 9.3 100 No Notes: 1. Pollutants emission rates are based on the maximum short-term emission rate of that pollutant provided by the chosen engine vendor in the engine specification sheet. Additional detail on potential short-term and annual emissions expected from the proposed facility will be discussed in the NOI. 2. Based on 100 operating hours per year for Fire Pump generators and 66 hours per year for all other generators 3. Taken from UDAQ’s Emissions Impact Assessment Guidelines.
The modeling thresholds for NO2 would be exceeded and therefore UDAQ requires dispersion modeling for annual NO2. Additionally, the applicant understands that UDAQ would like the proposed facility to demonstrate compliance with the 1-hour NO2 NAAQS since the proposed facility’s NOX emission will potentially exceed 10 pounds per hour.6F7 Consistent with UDAQ’s Emissions Impact Assessment Guidelines, some facilities must evaluate emissions of Hazardous Air Pollutants (HAPs) against UDAQ’s Emission Threshold Values (ETVs) for each pollutant. However, since the engines are subject to NSPS IIII, they are exempt from R307-410-57F8, as noted below:
“The requirements of R307-410-5 do not apply to installations which are subject to or are scheduled
to be subject to an emission standard promulgated under 42 U.S.C. 7412 at the time a notice of
5 Utah Division of Air Quality. New Source Review Section. 2013. Emissions Impact Assessment Guidelines. March. Available at: http://www.deq.utah.gov/Permits/air/docs/2013/03Mar/ EmissionsImpactAssessmentGuideline.pdf 6 Utah Office of Administrative Rules. 2019. Rule 307-410. Permits: Emissions Impact Analysis. July. Available at: https://rules.utah.gov/publicat/code/r307/r307-410.htm 7 Refer to Pre-NOI meeting held between eBay, Ramboll, and UDAQ on July 23, 2019.
8 Utah Administrative Code. R307-410-5. https://rules.utah.gov/publicat/code/r307/r307-410.htm
Air Dispersion Modeling Protocol
Modeling Methodology, Settings, and Inputs
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intent is submitted, [unless the director determines the delay in the implementation of an emission
standard might post an unacceptable risk to public health]. This exemption does not affect
requirements otherwise applicable to the source, including requirements under R307-401.8F9”

3. MODELING METHODOLOGY, SETTINGS, AND INPUTS
The following sections of this protocol establish the proposed methodologies that will be relied upon in the dispersion modeling analysis that will be submitted as part of the facility’s complete NOI application.
3.1 Model Selection and Settings To estimate off-property ambient air concentrations of NO2, the applicant will use the latest version of the AERMOD modeling system (19191), which is the United States Environmental Protection Agency’s (USEPA’s) recommended air dispersion model. AERMOD is appropriate for use in estimating ground-level, short-term ambient air concentrations resulting from non-reactive buoyant emissions from sources located in simple and complex terrain.
Modeled impacts will be estimated using AERMOD in conjunction with information about the site, the locations of the NOX-emitting stacks, representative meteorological data, and nearby receptors. The North American Datum of 1983 (NAD83) of the Universal Transverse Mercator (UTM) Coordinate System will be used, which provides a constant distance relationship anywhere on the map or domain. The units of the coordinates are in meters.
The applicant will use the Tier 3 Ozone Limit Method (OLM Group) model option to demonstrate compliance with the NO2 NAAQS. As part of the recent Appendix W updates, USEPA incorporated these model options as regulatory default methods for NO2 modeling. Model inputs specific to this methodology are discussed later in this protocol.
3.2 Source Emission Rates and Operational Restrictions The existing and proposed emergency standby generators will be the primary source of NOX emissions at the proposed facility, with relatively small emissions of NOx from the Bloom Energy Servers (<1 tpy). Short-term and annual emission rates are conservatively based on the manufacturer's "Not-to-Exceed" emissions data for each generator. Annual average emissions rates are conservatively based on operations at 100% load and are annualized according to the allowable non-emergency operating time per year. Estimates of the potential short-term (by load) and annual average emission rates (at 100% load) for the generators are provided in Appendix B.
Non-emergency operation (i.e. planned maintenance and testing) of the generators will be conducted in accordance with the operational limitations utilized in the modeling to achieve a passing scenario for the 1-hour NO2 NAAQS, incorporating the exhaust stack inputs and emission rates discussed above. Emergency operations are not regulated by UDAQ and, as such, are not included in the model or subject to operational limitations.
9 Utah Administrative Code. R307-401. Permit: New and Modified Sources. https://rules.utah.gov/publicat/code/r307/r307-401.htm
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Modeling Methodology, Settings, and Inputs
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3.3 Modeled Sources and Release Parameters Sources modeled as part of this analysis will consist of the 33 emergency standby generators and 2 fire pump engines. The pertinent release parameters will be based on information provided by the equipment manufacturer(s). Source parameters are included in Appendix B.
3.4 Building Downwash The AERMOD model incorporates Plume Rise Modeling Enhancements (PRIME) to account for downwash. The direction-specific building downwash dimensions used as inputs were determined by the latest version (04274) of the Building Profile Input Program, PRIME (BPIP PRIME). BPIP PRIME uses building downwash algorithms incorporated into AERMOD to account for the plume dispersion effects of the aerodynamic wakes and eddies produced by buildings and structures.
The applicant proposes to evaluate onsite buildings at the proposed facility for downwash effects on each modeled point source. Since the onsite buildings will have multi-tiered roofs, the tiered sections were treated as separate buildings for this modeling demonstration. The modeled dimensions for the buildings and the water storage tanks will be provided in the full modeling report submitted as part of the NOI application.
3.5 Good Engineering Practice Stack Height Analysis The USEPA has promulgated regulations that limit the maximum stack height one may use in a modeling analysis to no more than the Good Engineering Practice (GEP) stack height9F10. The purpose of this requirement is to prevent the use of excessively tall stacks to reduce the modeled concentrations of a pollutant. GEP stack height is impacted by the heights of nearby structures. In general, the maximum value for GEP stack height is 65 meters. The stack heights for the proposed generator stacks will not exceed the GEP stack height.
3.6 Receptor Grid The approximate property boundary and fence line are illustrated in Appendix A. Ground level receptors were placed along the fence line at approximately 10-meter intervals, resulting in 201 fence line receptors. Beyond the fence line, a variable density, discrete Cartesian receptor grid was used for the modeling assessment, as outlined in Table 2. This discrete receptor grid generated 9,470 receptors.
Table 2. Minimum Discrete Receptor Spacing
Distance from Fence Line Receptor Spacing
Along fence line 10 meters 0 – 250 meters 25 meters 250 – 1000 meters 50 meters 1,000 – 3,000 meters 100 meters 3,000 – 6,000 meters 200 meters 6,000 – 12,000 meters 500 meters
3.7 Terrain Data and Land Use Per USEPA guidance, terrain elevations were incorporated into the model using the most recent version (18081) of AERMAP, AERMOD’s terrain preprocessor. Terrain elevation data for the entire
10 USEPA. 1985. Guideline for Determination of Good Engineering Practice Stack Height. Revised. Available at: https://www3.epa.gov/ttn/scram/guidance/guide/gep.pdf
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Modeling Methodology, Settings, and Inputs
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modeling domain was extracted from 1/3 arc second National Elevation Data (NED) files with a resolution of approximately 10 meters. The NED files were obtained from the United States Geological Survey (USGS) Multi-Resolution Land Characteristics Consortium (MRLC).10F11 AERMAP was configured to assign elevations for the sources, buildings, property line receptors, and discrete gridded receptors in the modeling domain.
Land use classification determines the type of area to be modeled. The different classifications, urban or rural, incorporate distinct pollutant dispersion characteristics and will affect the estimation of downwind concentrations when used in the model. Based on the land use around the proposed facility, the urban boundary layer option in the model was not selected.
3.8 Meteorological Data AERMOD requires a meteorological input file to characterize the transport and dispersion of pollutants in the atmosphere. Surface and upper air meteorological data inputs, as well as surface parameter data describing the land use and surface characteristics near the site, are processed using AERMET (v18081), the meteorological preprocessor to AERMOD. The output file generated by AERMET is the meteorological input file required by AERMOD.
A pre-processed surface and upper air meteorological data set for the Salt Lake City airport was provided by UDAQ for this modeling assessment for five continuous meteorological years (2008-2012).11F12
3.9 Background Data The NO2 and O3 background data used in this modeling exercise was developed from hourly NO2 and O3 data from the Air Quality System (AQS) Data Mart database for the Herriman station (AQS ID: 49-035-3013) for the most recent three-year period of available data (January 2016 through December 2018).12F13 Background concentrations were calculated using the three year average of the 3rd highest value of the available monitoring data, determined by accounting for both season and hour-of-day.13F14 Completed NO2 and O3 background datasets will be provided as part of the Modeling Report that will be submitted in support of the NOI application. These datasets can also be provided to UDAQ for review upon request.
3.10 In-Stack Ratio (NO2 to NOX Conversion) The applicant proposes to use a NO2/NOX in-stack ratio of 0.10 for the facility’s proposed emergency generators. This value was selected based on data obtained from the USEPA’s In-Stack Ratio Database for diesel/kerosene-fired reciprocating internal combustion engines (RICE). The USEPA database has data for 57 diesel-fired RICE that indicate a median, mean, and even a second-high value, that are less than a 0.10 NO2/NOX ratio.
3.11 Nearby Sources Per input from UDAQ,14F15 three existing nearby sources were identified for possible inclusion in the cumulative analysis (Figure A3). The inclusion of the nearby sources in the modeling depends on the modeled concentrations from the Project (plus background) compared to the NAAQS. Ramboll

11 http://www.mrlc.gov 12 Meteorological data for Salt Lake City Airport for 2008 through 2012 provided by Dave Prey (UDAQ) on May 1, 2019. 13 Background monitoring data recommendations provided by Dave Prey of UDAQ on May 1, 2019. 14 https://www.epa.gov/sites/production/files/2015-07/documents/appwno2_2.pdf 15 Nearby source information was provided by Dave Prey (UDAQ) on May 23, 2019.
Air Dispersion Modeling Protocol
Modeling Methodology, Settings, and Inputs
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would include the largest of the three sources if Project-only (plus background) impacts are greater than 85% of the NAAQS and would include all three sources if Project-only (plus background) impacts are greater than 90% of the NAAQS, at the Point of Maximum Impact (PMI).15F16 These facilities would be included in the modeling analysis using emissions and exhaust parameter data provided by UDAQ for NOx.

16 Per email correspondence with Dave Prey on June 28, 2019.
Air Dispersion Modeling Protocol
Modeled Impacts Analysis
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4. MODELED IMPACTS ANALYSIS
This section outlines the technical approach that is being proposed within the context of this dispersion modeling evaluation. Detailed results of the modeling analysis will be provided as part of the NOI submittal following approval of this modeling protocol.
Typically, a Significance Analysis is required to determine whether a proposed project could cause a significance impact on the surrounding area. A significant impact may occur if ambient concentrations exceed the Significant Impact Levels (SIL; 7.5 µg/m3 for 1-hr NO2 and 1 µg/m3 for Annual NO2).16F17 If the maximum modeled concentration for all averaging periods for a given pollutant are below the SIL when project emissions increases are modeled, no further analysis is required for that pollutant. Otherwise, a NAAQS analyses is required for that pollutant and averaging period. Ramboll anticipates that project impacts will be above the SIL for the 1-hr and Annual averaging periods and thus proposes not to conduct significance modeling and will move forward with a NAAQS analysis for all required pollutants and averaging period.
This air quality assessment will evaluate modeled impacts from the project sources (i.e., emergency generators), plus representative background concentrations and nearby source, if applicable, to determine compliance with the primary 1-hour and annual NO2 NAAQS, as presented in Table 3. The proposed receptors discussed above will be included in the assessment to demonstrate compliance with the NAAQS. Ramboll will conduct modelling for the Project first and proceed with a cumulative impact analysis based on the criteria discussed in section 3.11. Plots of modeled concentrations for each averaging period will be provided with the Final Modeling Report to show the location of the maximum concentration and how the modeled concentrations vary across the domain.

Table 3. Applicable NAAQS
Pollutant Averaging
Period
Primary NAAQS
(µg/m3)
NO2 1-Hour 188 1
Annual 100 2
Notes:
1. Standard of 100 ppb converted to µg/m3. 98th percentile of 1-hour daily maximum concentrations, averaged over 3 years.
2. Standard of 53 ppb converted to µg/m3. Annual mean.

17 EPA has not promulgated a 1-hour NO2 SIL. The interim SIL of 7.5 µg/m3 is based on EPA’s recommended value of 4% of the 1-hour NO2 NAAQS (4 ppb), per U.S. EPA, Office of Air Quality Planning and Standards, Memorandum from Mr. Stephen Page to Regional Air Division Directors. Guidance Concerning the Implementation of the 1-hour NO2 NAAQS for the Prevention of Significant Deterioration Program (June 29, 2010).

APPENDIX A
FIGURES
!
!
!
!
!
!
!!
!
!
!
^_
Orem
Sandy
Provo
Ogden
Layton
Millcreek
West JordanTaylorsville
South Jordan
Salt Lake City
50 West Broadway, Suite 300Salt Lake City, UT 84101
0 20
Kilometers
FIGUREA1Facility Location andSurrounding AreaseBay Data CenterSouth Jordan, Utah
Arizona
Nevada
Idaho
Wyoming
Colorado
£¤89
§¨¦15
^_FacilityStreets
U.S Interstates
Highways
State
County
WASATCHCOUNTY
TOOELECOUNTY
SUMMITCOUNTY
BOX ELDERCOUNTY
DAVISCOUNTY
WEBERCOUNTY
MORGANCOUNTY
UTAHCOUNTY
SALTLAKECOUNTY§¨¦80
§¨¦84
eBayDataCenter
eBayDataCenter
FP
1
G0
1
G0
2
G0
3
G0
4
G0
5
G0
6
G0
7
G0
9
G1
0
G2
4G2
5
G2
6
G2
7
G08
G28G29G30G31G33G32
G11G12
G13G14FP2
G15G16G17G18G19G20G21G22G23
Source: Esri, DigitalGlobe, GeoEye, Earthstar Geographics, CNES/Airbus DS, USDA, USGS, AeroGRID,IGN, and the GIS User Community
Site Layout with Generators (Existing and Proposed)
DRAFTED BY: LEWIS KUNIK DATE: 7/22/2019 PROJECT: 1690013291
0 200
SCALE IN FEET
FIGUREA2eBay Data Center6614 West Crimson View DriveSouth Jordan, UT 84095
Legend
ProposedGenerators
Existing Generators
Buildings
Ambient AirBoundary
C:\Users\mtrail\Documents\ebay\receptor_sitemap.mxd
#*
#*
#*
Source: Esri, DigitalGlobe, GeoEye, Earthstar Geographics, CNES/AirbusDS, USDA, USGS, AeroGRID, IGN, and the GIS User Community
DRAFTED BY:LEWIS KUNIK DATE: 3/31/2020
0 2
Kilometers
PROJECT: 1690013291
FIGUREA3Model Receptor Grid and Nearby SourceseBay Data Center6614 West Crimson View DriveSouth Jordan, UT 84095
Trans-Jordan Landfill Interstate Brick Co.
Hexcel Corporation
Legend
#*NearbySources
Ambient AirBoundary
ModelReceptors
APPENDIX B
SOURCE PARAMETERS
X (m)Y (m)Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack Release
Velocity (m/s)
Stack
Emission
Rate (g/s)
Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack Release
Velocity (m/s)
Stack Emission
Rate (g/s)
Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack Release
Velocity (m/s)
Stack Emission
Rate (g/s)4
FP1 411232.8 4490852.7 1550.7 0.13 2.3 ----------------100 779.26 26.31 0.001
G01 411271.9 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G02 411283.5 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G03 411295.4 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G04 411307.8 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G05 411319.4 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G06 411331.2 4490965.9 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G07 411343.2 4490965.7 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 0.153
G08 411325.9 4490763.3 1550.7 0.61 8.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G09 411212.9 4490750.5 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G10 411195.0 4490755.3 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G11 411383.2 4490795.9 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G12 411383.2 4490802.0 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G13 411383.5 4490821.7 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G14 411383.5 4490828.0 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,000 751.32 39.29 0.160
G24 411314.9 4490726.4 1550.7 0.46 6.1 650 621.38 22.02 0.555 1,750 671.04 42.25 3.709 2,500 727.98 54.07 0.124
G25 411320.7 4490726.4 1550.7 0.46 6.1 650 621.38 22.02 0.555 1,750 671.04 42.25 3.709 2,500 727.98 54.07 0.124
G26 411326.4 4490726.8 1550.7 0.46 6.1 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G27 411331.8 4490726.8 1550.7 0.46 6.1 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
FP2 411115.1 4490830.2 1555.5 0.13 10.6 ----------------64 744.26 17.18 0.001
G15 411130.4 4490924.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G16 411130.5 4490917.8 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G17 411130.8 4490911.3 1555.5 0.46 7.2 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 0.073
G18 411130.7 4490904.9 1555.5 0.46 7.2 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 0.073
G19 411130.3 4490898.5 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G20 411130.3 4490892.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G21 411130.3 4490885.6 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G22 411130.3 4490879.2 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G23 411130.8 4490872.8 1555.5 0.46 6.7 300 632.93 4.46 0.346 700 705.98 7.63 1.336 1,000 751.21 8.93 0.044
G28 (proposed)411130.4 4490970.7 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G29 (proposed)411130.4 4490964.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G30 (proposed)411130.4 4490957.3 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G31 (proposed)411130.4 4490950.7 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 0.097
G32 (proposed)411130.8 4490944.0 1555.5 0.51 7.2 250 706.19 7.42 0.331 600 763.54 11.23 1.165 750 780.76 12.86 0.034
G33 (proposed)411130.8 4490937.2 1555.5 0.51 7.2 250 706.19 7.42 0.331 600 763.54 11.23 1.165 750 780.76 12.86 0.034
Notes1 Generator locations and release heights and stack diameters were provided by eBay. Emission rates, exhaust temperature and release velocity were retrieved from engine manufacturer spec sheets.2 Coordinates are based on NAD 1983 datum Zone 12N.
4 Annual average NO2 modeling will include all generators and parameters assuming 100% load. The emission rates are annualized assuming 100 hours per year for the fire pumps and 66 hours per year for all other generators.
Coordinates2
Elevation
(m)
Stack
Diameter
(m)
Stack
Release
Height (m)2
3 Monthly generator testing of generators G1-G7 occur 4 generators at a time while other generators occur 2 or 1 at a time. Monthly tests for all non-fire-pump engines occur for 30 minutes at a time at the engine load specified in this Table. Annual tests of all non-fire-pump generators are modeled one at a time for a full hour at the engine load specified in this Table. All monthly and annual tests would occur between 8 a.m. and 6 p.m. Fire pump engines were not included in 1-hr NO2 modeling since emissions from these engines are small and they are unlikely to be tested simultaneously with other generators.
Generator1
Table B1
Air Model Input Parameters
eBay Data Center
South Jordan, Utah
Monthly Test Parameters3 Annual Test Parameters3
1-hr NO2 Model Inputs Annual NO2 Model Inputs
100% Engine Load (Annualized)
Page 1 of 1
Air Dispersion Modeling Report
eBay SLC Data Center
Ramboll
Confidential
ATTACHMENT D
ELECTRONIC MODELING FILES

Confidential

Intended for Utah Division of Air Quality
Prepared for eBay
South Jordan, Utah
Prepared by Ramboll US Consulting
Salt Lake City, UT
Project Number
1690023502
Date July 2023

NOTICE OF INTENT APPLICATION
EBAY SLC DATA CENTER
SOUTH JORDAN, UTAH

Notice of Intent Application eBay SLC Data Center
Contents i Ramboll
Confidential
CONTENTS

1. INTRODUCTION 1
2. FACILITY DESCRIPTION 2
3. EMISSIONS CALCULATIONS 3
3.1 Diesel-Fired Emergency Standby Generators 3
3.2 Diesel Storage Tanks 4
3.3 Cooling Towers 4
3.4 Potential Emissions 4
Notice of Intent Application eBay SLC Data Center
Contents i Ramboll
Confidential
TABLES
Table 1. Generator IDs 2
Table 2. Facility-Wide Potential Emissions 5
Table 3. Potential to Emit: Criteria Pollutants & GHG 6

APPENDICES
Appendix 1
Site Location Map
Appendix 2
UDAQ Facility Modification Forms
Appendix 3
Generator Manufacturer Specifications and Emissions Data Sheets
Appendix 4
Potential Emissions Calculations

Notice of Intent Application eBay SLC Data Center
Facility Description 1 Ramboll
Confidential
1. INTRODUCTION
eBay Inc. (“eBay” or “the applicant”) is submitting this Notice of Intent (NOI) Application to
the Utah Department of Environmental Quality – Division of Air Quality (UDAQ) to request
authority to update DAQE-AN141800011-21. With this Approval Order (AO) modification,
eBay proposes to update the operational hours of two diesel-fired emergency generators
from 66 hours a year to 100 hours a year, and reduce the operational hours for twenty-nine
(29) diesel-fired emergency generators from 66 hours a year to 60 hours a year. The
applicant is also requesting to relocate two diesel-fired emergency backup generators,
remove two diesel-fired emergency generators from the permit, and remove the Bloom
Energy Servers at eBay’s SLC Data Center (facility) located in South Jordan, Salt Lake
County, Utah.
The Northern Wasatch Front Nonattainment Area is anticipated to be reclassified from
moderate to serious ozone nonattainment status in February 2025.1 This reclassification
reduces the Title V Major Source threshold from 70 tons per year (tpy)2 to 50 tpy for ozone
precursors including both NOx and VOC. eBay is currently permitted as a synthetic minor
source with the potential to emit (PTE) of 57 tons of NOx per year. Because eBay's PTE
exceed the proposed major source threshold of 50 tpy, UDAQ requires that eBay either
complete a RACT analysis for the emissions units at the facility, or submit a Notice of Intent
(NOI) application to lower the PTE below 50 tpy of NOx and VOCs to remain a minor source.
eBay elects to submit an NOI to reduce PTE below 50 tpy of NOX and VOC.
As a result of the changes described in this NOI application, eBay’s NOx emissions would
decrease from 57 tpy of NOx to 49.94 tpy of NOx, which is below the lower 50 tpy threshold.
eBays VOC emissions will continue to remain below the 50 tpy VOC threshold.
The facility currently includes 31 diesel-fired emergency backup generators that provide
electricity to the facility in the event of an emergency, two fire pump engines, and two
cooling towers. Site location maps are provided in Appendix 1.
The facility is currently classified as a synthetic minor source of air emissions with respect to
the Title V and New Source Review (NSR) permitting programs. Since the project decreases
the potential to emit of all air pollutants, a full Notice of Intent (NOI) application is not
required, but eBay is required to notify UDAQ of the modifications in accordance with the
requirements of the Utah Administrative Code (UAC) Rule 307-401-12.3 Approval for the
proposed actions to reduce NOx emissions below the 50 tpy threshold could be achieved
mirroring the process of a R307-401-12 administrative amendment.4 The applicant is hereby
requesting an Approval Order (AO) modification from UDAQ to cover increased operating
hours of two generators, decreased operating hours of twenty-nine (29) generators,
relocation of three generators, as well as the removal of two existing generators and the
Bloom Energy Servers at the facility.

1 Letter from UDAQ to eBay dated May 31, 2023, and Northern Wasatch Front Serious Ozone SIP Stakeholder
Meeting, held Jun 13, 2023.
2 Currently applicable for PM2.5 precursors. 3 Utah Administrative Code. R307-401-12. Permit: New and Modified Sources. Approval Order. Available at: https://adminrules.utah.gov/public/rule/R307-401/Current%20Rules?
4 Email from John Jenks (UDAQ) to Megan Neiderhiser on June 27, 2023
Notice of Intent Application eBay SLC Data Center
Facility Description 2 Ramboll
Confidential
2. FACILITY DESCRIPTION
The applicant is proposing to do following changes to the data center located in Salt Lake
County, Utah.
1) increasing hours of operation for G15 and G16 from 66 operational hours per year to 100
operational hours per year,
2) decreasing hours of operation for G01-G14, G17-G29, and G32-33 from 66 operational
hours per year to 60 operational hours per year,
3) relocation of generators G26 and G27 to G30 and G31 locations,
4) removal of G30 and G31 from the permit,
5) removing the Bloom Energy Servers.
A list of the post change generator identification (ID) numbers is provided in Table 1, a
facility map of generator locations is provided in Appendix 1, and the manufacturer’s
specification sheets for the generators are provided in Appendix 3.5
Table 1. Generator IDs
Emission Point ID Numbers for Generators Generator Manufacturer and Engine Size (per engine)
G1-G7 Detroit Diesel - 3.25 Megawatts
(MW)
G8-G14 Caterpillar - 3.0-3.1 MW
G15-G16; G19-G22; G26-
G27 Caterpillar - 2.0 MW
G17-G18 Caterpillar - 1.5 MW
G23 Caterpillar - 1.0 MW
G24-G25 Caterpillar - 2.5 MW
FP1 Caterpillar - 100 kilowatts (kW)
FP2 John Deere - 64 kW
G28-G29 Caterpillar - 2.0 MW
G32-G33 Caterpillar - 750 kW

Other sources of emissions at the facility include diesel storage tanks for each generator, and
two cooling towers. The cooling towers would not be changed as part of this modification,
and emissions from diesel storage tanks are negligible.

5 Emission specification sheets are included for all existing and proposed generators at the facility since emissions
of existing engines were revised to conservatively utilize not-to-exceed factors instead of nominal emissions factors, which were previously used in potential emissions calculations.
Notice of Intent Application eBay SLC Data Center
Emissions Calculations 3 Ramboll
Confidential
3. EMISSIONS CALCULATIONS
Pollutants emitted from the facility include NOX; CO; VOCs; sulfur dioxide (SO2); particulate
matter (PM); PM less than 10 microns in diameter (PM10); PM less than 2.5 microns in
diameter (PM2.5); hazardous air pollutants (HAPs); and greenhouse gases, represented in
terms of carbon dioxide equivalents (CO2e).
The methodology used to estimate the potential emissions from each source is discussed in
the following sections. The manufacturer’s specification sheets for the generators are
provided in Appendix 3, and detailed calculations are provided for all emissions sources in
Appendix 4.
3.1 Diesel-Fired Emergency Standby Generators
Operation of the diesel-fired emergency generator engines would result in emissions of
byproducts of combustion. The derivation of potential hourly and annual emissions is
presented below.
3.1.1 Derivation of Potential Hourly Emissions
The following emission factors were used to estimate the potential hourly emissions from the
emergency generators:
• Except as noted below, the manufacturer’s not-to-exceed, engine-specific emission factors
for NOX, VOC (hydrocarbons), CO, and filterable PM were used to estimate the emissions
of those pollutants at each generator load. It was conservatively assumed that all
particulate matter in the engine exhaust is PM2.5. Potential hourly emissions were based
on the maximum hourly emission rate for each pollutant at any engine load for each
engine group.
– Note, for engines G1-G7, the manufacturer provided emissions on a mechanical
kilowatt (kWm) basis. Therefore, the engine rating used for emissions calculations is
3,490 kWm. However, the engine rating in the current AO is in electrical megawatt
(MWe). Thus, Table 1 lists the engine rating in MWe (i.e. 3.25 MW), which is
consistent with all other engines which are listed in electrical wattages.
• For all engines except the fire pumps, emissions of SO2, condensable PM, and HAP were
estimated based on the diesel fuel emission factors in the USEPA’s AP-42, Chapter 3.4,
Large Stationary Diesel and All Stationary Dual-fuel Engines (October 1996). The
emission factor for SO2 was calculated based on the maximum allowable diesel fuel sulfur
content of 0.0015% by weight, per 40 CFR 60 Subpart IIII. The emissions calculations
assumed a diesel high heating value of 0.137 MMBtu/gal, based on AP-42, Table 3.4-1,
footnote a.
• For fire pump engines, emissions of SO2 and HAP were estimated based on the diesel fuel
emission factors in the USEPA’s AP-42, Chapter 3.3, Gasoline and Diesel Industrial
Engines, Table 3.3-2 (October 1996). It was conservatively assumed that the fire pumps
have the same condensable PM emissions factor as Large Stationary Diesel and All
Stationary Dual-fuel Engines.
• Emissions of CO2e from diesel fuel combustion were estimated based on the GHG emission
factors and global warming potentials provided in 40 CFR 98.
Notice of Intent Application eBay SLC Data Center

Confidential
3.1.2 Derivation of Potential Annual Emissions
Potential annual emissions from the facility were estimated assuming 60 hours per year per
engine for all existing and proposed generators except for generators G15 and G16, and 100
hours per year for the two fire pump engines and G15 and G16. The operational limit of 100
hours per year for generators is requested to meet the 100 hours per year maximum
allowable non-emergency run time per 40 CFR 60 Subpart IIII.6
3.2 Diesel Storage Tanks
Emissions of VOC from the diesel tanks would result from the standing and working losses.
Consistent with previous permitting applications, these emissions are considered negligible
and are not included as part of this application.
3.3 Cooling Towers
Emissions of PM from the two cooling towers are the result of the cooling water coming into
direct contact with the air through the tower and causing water droplets to carry PM from the
cooling towers. The emissions are based on the cooling tower recirculation rate, total
dissolved solids content in the cooling water, the drift loss from the tower, and the particle
size after evaporation of the water. These emissions were estimated by using the method
from Calculating Realistic PM10 Emissions from Cooling Towers.7 Potential annual emissions
were based on 8,760 hours per year of operation. Cooling tower emissions have not
changed as a result of this application.
3.4 Potential Emissions
A summary of the potential emissions for the facility are provided in Table 2, and indicate
that the facility would be a minor source of air emissions.8 As the project does not increase
the potential to emit of any air pollutant or cause emissions of any new air pollutant, the
applicant is exempt from the requirement to conduct air dispersion modeling.
6 As confirmed via phone conversation with UDAQ, the agency does not regulate run time or emissions resulting from emergency operations of the generators. Additionally, the agency does not regulate run time or emissions during the initial shakedown period of new engines prior to the engines becoming operational, not to exceed 180 days, in accordance with the definition of “Net Emissions Increase” in UAC Rule 307-101-2. Available at: https://adminrules.utah.gov/public/rule/R307-101/Current%20Rules?
7 Joel Reisman and Gordon Frisbie. Calculating Realistic PM10 Emissions from Cooling Towers. Available at:
https://www.nrc.gov/docs/ML1232/ML12325A097.pdf 8 In previous NOI submittals, nominal emissions data was used to calculate potential emissions. As part of this
application, emissions from existing emergency generators use not-to-exceed manufacturer emissions data for a more conservative approach, following the methodology used in DAQE-AN141800011-21.
Notice of Intent Application eBay SLC Data Center
Emissions Calculations 5 Ramboll
Confidential
Table 2. Facility-Wide Potential Emissions
Pollutant
Potential Annual Emissions (tpy) Facility-Wide Potential Annual Emissions (tpy)
Title V Major Source Threshold1,2,3 (tpy)
Above Threshold? Emergency
Generators & Fire
Pumps
Cooling Towers
NOX 49.94 -- 49.94 70 No
CO 5.89 -- 5.89 100 No
VOC 1.15 -- 1.15 50 No
PM 0.63 3.04 3.67 100 No
PM10 0.63 2.29 2.92 100 No
PM2.5 0.63 6.84E-03 0.64 70 No
SO2 0.056 -- 0.056 70 No
Maximum
Individual
HAP
(Benzene)
0.0048 -- 0.0048 10 No
Total HAP 0.036 -- 0.036 25 No
CO2e 3677.7 -- 3677.73 N/A N/A

Notes:
1) UAC R307-420 applies when Salt Lake County is designated as a maintenance area with respect to the 2015 8-hr Ozone National Ambient Air Quality
Standard (NAAQS). Salt Lake County is currently classified as Moderate nonattainment for the Ozone standard. However, UAC does not have
regulations codified for when Salt Lake County is designated as nonattainment, and therefore, the Major Source classification for VOC from UAC R307-
420 was used. UAC R307-420 available at: https://rules.utah.gov/publicat/bulletin/2017/20170601/41641.htm.
2) Utah Administrative Code. R307-403. Permit: New and Modified Sources in Nonattainment Areas and Maintenance Areas.
https://rules.utah.gov/publicat/code/r307/r307-403.htm#E2.
3) The Major Source threshold is anticipated to be reduced from 70 tons per year (tpy) to 50 tpy for ozone precursors, including both NOx and VOC, in
February 2025.

Notice of Intent Application eBay SLC Data Center

Confidential
Table 3. Potential to Emit: Criteria Pollutants & GHG
Criteria Pollutants Current Permitted Emissions (tons / year) Proposed Emissions Changes (tons/year) Proposed Emissions (tons/year)
PM10 (Total) 3.00 -0.079 2.92
PM10 (Fugitive) -- -- --
PM2.5 0.71 -0.080 0.63
NOX 56.35 -6.41 49.94
SO2 0.060 -3.51E-03 0.056
CO 11.38 -5.49 5.89
VOC 2.26 -1.11 1.15
VOC (Fugitive) -- -- --
NH3 -- -- --
Greenhouse Gases Mass Basis CO2e Mass Basis CO2e Mass Basis CO2e
CO2 -- -- -- -- 3,665.16 3,665.16
CH4 -- -- -- -- 0.15 3.72
N2O -- -- -- -- 0.03 8.86
HFCs -- -- -- -- -- --
PFCs -- -- -- -- -- --
SF6 -- -- -- -- -- --
Total CO2e 41,355.00 41,355.00 -37,677.27 -37,677.27 3,677.73 3,677.73
Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential
APPENDIX 1
FIGURES
!
!
!
!
!
!
!!
!
!
!
^_
Orem
Sandy
Provo
Ogden
Layton
Millcreek
West JordanTaylorsville
South Jordan
Salt Lake City
50 West Broadway, Suite 300Salt Lake City, UT 84101
0 20
Kilometers
FIGUREA1Facility Location andSurrounding AreaseBay SLC Data CenterSouth Jordan, Utah
Arizona
Ne
v
a
d
a
Idaho
Wyoming
Co
l
o
r
a
d
o
£¤89
§¨¦15
^_FacilityStreets
U.S Interstates
Highways
State
County
WASATCHCOUNTY
TOOELECOUNTY
SUMMITCOUNTY
BOX ELDERCOUNTY
DAVISCOUNTY
WEBERCOUNTY
MORGANCOUNTY
UTAHCOUNTY
SALTLAKECOUNTY§¨¦80
§¨¦84
eBayDataCenter
eBay
SLC DataCenter
G11G12
G13G14FP2
G15G16G17G18G19G20G21G22G23
G09
FP
1
G0
1
G0
2
G0
3
G0
4
G0
5
G0
6
G0
7
G1
0
G2
4
G2
5
G08
G28G29
G27
G33G32
G26
Salt Lake County, Maxar, Microsoft
Site Layout with Generators
PROJECT: 1690013291
0 200
SCALE IN FEET
FIGURE
A2eBay Data Center
6614 West Crimson View Drive
South Jordan, UT 84095
Legend
Generators
Buildings
Ambient Air
Boundary
Notice of Intent Application eBay SLC Data Center
Ramboll
APPENDIX 2
UDAQ APPROVAL ORDER MODIFICATION 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
2
3
4
5
6
7
8
9
NOI Application Information [R307‐401]
1
2
3
4 N/A
5
6
A
7
A
B
C
8
A
9
A N/A
B N/A
10
A N/A
B N/A
Signature on Application
Note: The Division for Air Quality will not accept documents containing confidential information or 
data. Documents containing confidential information will be returned to the Source submitting the 
application.
Nonattainment/Maintenance Areas ‐ Major NSR/Minor (Offsetting Only) [R307‐403]
NAAQS Demonstration, Lowest Achievable Emission Rate, Offset 
Requirements.
Alternate site analysis, Major source ownership compliance certification.
Major Sources in Attainment or Unclassified Area (PSD) [R307‐405, R307‐406]
Air quality analysis (air model, met data, background data, source impact 
analysis).
Visibility impact analysis, Class I area impact.
Composition and physical characteristics of effluent
(Emission rates, temperature, volume, pollutant types, and concentration).
Discussion of fuels, raw materials, and products consumed/produced.
Description of equipment used in the process and operating schedule.
Description of changes in the process, production rates, etc.
Site plan of source with building dimensions, stack parameters, etc.
Best Available Control Technology (BACT) Analysis [R307‐401‐8]
BACT analysis for all new and modified equipment.
Emissions Related Information [R307‐401‐2(b)]
Emission calculations for each new/modified units and site‐wide
(Include PM10, PM2.5, NOX, SO2, CO, VOCs, HAPs, and GHG).
References/assumptions, SDS, for each calculation and pollutant.
All speciated HAP emissions (list in lbs/hr).
Emissions Impact Analysis ‐ Approved Modeling Protocol [R307‐410]
Detailed description of the project and source process.
7/26/2023
eBay Inc.
Company name, mailing address, physical address, and telephone number.
Company contact (name, mailing address, telephone number).
Name and contact of person submitting NOI application (if different than 2).
Source Universal Transverse Mercator (UTM) coordinates.
Source Standard Industrial Classification (SIC) Code.
Area designation (attainment, maintenance, or nonattainment).
Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.)
Source size determination (Major, Minor, PSD).
Current Approval Order(s) and/or Title V Permit Numbers.
# Confidential
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
1. Company name and mailing address:2. Company** contact for environmental matters:
Company Name:Contact:
Title:
Phone No.:
Phone No.:Email:
Fax No.:
3. Source name and physical address (if different from above):
Company Name:SLC Data Center
Mailing Address:6614 West Crimson View Drive UTM E:meters
South Jordan, UT 84095 UTM N:meters
Phone No.:System & Datum:
Fax No.:
5. The Source is located in:County. 6. Standard Industrial Classification Code
7. If request for modification, AO# to be modified:
DAQE #:
Dated:
8. Brief (50 words or less) description of process:
Electronic NOI
Hard Copy Submittal:Electronic Copy Submittal:Both:
Title:
Telephone No:
Email:Date:
(415) 301‐1016
Eileen Ovrahim [e-mail] 
Name (Type or Print)
Signature:Regional Facilities Operations 
Manager
4490858.0
NAD83, Zone 12 N
Salt Lake
7374
DAQE‐AN141800011‐21 
7‐Jan‐21
Please see Section 2 of the enclosed NOI application report.
9. A completed and accurate electronic NOI submitted to DAQ Permitting Managers Jon Black ([e-mail]) or Alan
Humpherys ([e-mail]) can expedite review process. Please mark application type.
General Owner and Source Information
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.
411299.0
7/26/2023
General Owner and Source Information
eBay Inc. Eileen Ovrahim
Mailing Address:2145 Hamilton Ave Regional Facilities Operations 
Manager
San Jose, CA 95125 (415) 301‐1016
(408) 376‐8488 [e-mail] 
(408) 376‐5945 **Company contact only; consultant or independent contractor 
contact information can be provided in a cover letter.
4. Source Property Universal Transverse Mercator 
Coordinates (UTM), including System and Datum:
# Confidential
7/27/2023
Form 4 Company:
Emissions Information Site:
Criteria / GHGs
Utah Division of Air Quality
New Source Review Section
If submitting a new permit, then use Form 3
3. Permit Change Type: New Increase*
Yes No
*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.
Emitting Unit(s) Capacity(s) Manufacture Date(s)
6.   Description of Permit/Process Change** See details in application report
7.   New or modified materials and quantities used in process. **
Material Quantity Annually
G15‐G16 hours of operation 100 hrs/yr/generator for Non‐Emergency Operations
G01‐G14, G17‐G29, and G32‐G33 hours of operation 60 hrs/yr/generator for Non‐Emergency Operations
8.  New or modified process emitting units **
Hours limits for generators G1‐G29, and G32‐G33; See below
2.  Name of process to be modified/added:
Emergency generator Equipment
Process
End product of this process:
Removal of two emergency generators from the overall 
operation of facility; relocation of two generators; Non‐
Emergency runtime hour limits modified for existing permitted 
generators; removal of servers
Condition Change:1) relocation of generators G26 and G27 
to G30 and G31 locations, with the 
subsequent removal of G30 and G31;
2) increasing hours of operation for G15 
and G16 from 66 operational hours per 
year to 100 hours per year;
3) Decreasing hours of operation from 66 
operational hours per year to 60 
operational hours per year for G01‐G14, 
G17‐G29, and G32‐G33; and
4) removal of the Bloom Energy Servers
Other:
4.  Does new emission unit affect existing permitted process 
limits?
5.    Condition(s) Changing:
Requested Changes
eBay Inc.
SLC Data Center
Process Data  ‐  For Modification/Amendment ONLY
1. Permit Number DAQE‐AN141800011‐21 
# Confidential
Form 5 Company:
Emissions Information Source:
Criteria / GHGs
Utah Division of Air Quality
New Source Review Section
CO2eCO2eCO2e
‐‐ ‐‐3,665.16
‐‐ ‐‐3.72
‐‐ ‐‐8.86
‐‐ ‐‐ ‐‐
‐‐ ‐‐ ‐‐
‐‐ ‐‐ ‐‐
41,355.00 ‐37,677.27 3,677.73
*Potential to Emit to include pollution control equipment as defined by R307‐401‐2.
Form 5 Company:
Emissions Information Source:
HAP's
Utah Division of Air Quality
New Source Review Section
**Defined in Section 112(b) of the Clean Air Act.
***Use additional sheets for pollutants if needed.
Acrolein ‐‐ ‐‐1.84E‐04 ‐‐
Total HAP 0.12 ‐0.084 0.036 ‐‐
Formaldehyde ‐‐ ‐‐1.86E‐03 ‐‐
Acetaldehyde ‐‐ ‐‐6.24E‐04 ‐‐
Xylenes ‐‐ ‐‐4.35E‐03 ‐‐
1,3‐Butadiene ‐‐ ‐‐3.04E‐06 ‐‐
Benzene ‐‐ ‐‐0.017 ‐‐
Toluene ‐‐ ‐‐6.33E‐03 ‐‐
eBay Inc.
Facility‐Wide
Hazardous Air Pollutants**
Hazardous Air Pollutants***
Permitted 
Emissions
(tons/year)
Emissions 
Increases
(tons/year)
Proposed 
Emissions
(tons/year)
Emissions Increase
(pounds/hour)
SF6 ‐‐ ‐‐ ‐‐
Total CO 2e 41,355.00 ‐37,677.27 3,677.73
HFCs ‐‐ ‐‐ ‐‐
PFCs ‐‐ ‐‐ ‐‐
CH4 ‐‐ ‐‐0.15
N2O ‐‐ ‐‐0.03
Greenhouse Gases Mass Basis Mass Basis Mass Basis
CO2 ‐‐ ‐‐3,665.16
NH3 ‐‐ ‐‐ ‐‐
VOC 2.26 ‐1.11 1.15
VOC (Fugitive)‐‐ ‐‐ ‐‐
SO2 0.060 ‐3.51E‐03 0.056
CO 11.38 ‐5.49 5.89
PM2.5 0.71 ‐0.080 0.63
NOX 56.350 ‐6.41 49.94
PM10 (Total)3.00 ‐0.079 2.92
PM10 (Fugitive)‐‐ ‐‐ ‐‐
eBay Inc.
Facility‐Wide
Potential to Emit* ‐ Criteria Pollutants & GHGs
Criteria Pollutants Permitted Emissions
(tons / year)
Emissions Increases
(tons/year)
Proposed Emissions
(tons/year)
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate ‐‐gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
237
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
4,678.00 3,250.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
15,642 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.‐‐
4,678.00 3,250.00
Detroit Diesel N/A N/A
20V4000G83L N/A N/A
eBay Inc.
G1‐G7
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G1‐G7
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G1‐G7 Detroit Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM10
PM2.5
SO 2
CO2
CH 4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 122 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
211
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
4,376.00 3,100.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
13,906 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.‐‐
4,376.00 3,100.00
Caterpillar N/A N/A
C175‐16 N/A N/A
eBay Inc.
G8‐G14
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G8‐G14
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G8‐G14 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
138
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
2,937.00 2,000.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
13,800 ‐‐
137,030
N/A N/A
100 hrs/yr/generator for non‐emergency operations.
‐‐
2,937.00 2,000.00
Caterpillar N/A N/A
3516C N/A N/A
eBay Inc.
G15‐G16
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G15‐G16
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G15‐G16; G19‐G22; 
G26‐G27 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G19‐G22, G26‐G27
7/26/2023
Equipment Information
Average Maximum
Caterpillar N/A N/A
3516C N/A N/A
N/A N/A
60 hrs/yr/generator for non‐emergency operations.
‐‐
2,937.00 2,000.00
< 0.0015 Neg.
2,937.00 2,000.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
8,280 ‐‐
137,030
138
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G19‐G22, G26‐G27
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
G15‐G16; G19‐G22; 
G26‐G27 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 60 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
105
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
2,206.00 1,500.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
6,904 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.‐‐
2,206.00 1,500.00
Caterpillar N/A N/A
3512C N/A N/A
eBay Inc.
G17‐G18
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G17‐G18
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G17‐G18 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 40 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
72
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
1,483.00 1,000.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
4,778 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.‐‐
1,483.00 1,000.00
Caterpillar N/A N/A
C32 N/A N/A
eBay Inc.
G23
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G23
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G23 CAT Diesel 
Generator
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 99 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
175
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
3,633.00 2,500.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
11,550 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.‐‐
3,633.00 2,500.00
Caterpillar N/A N/A
3516C N/A N/A
eBay Inc.
G24‐G25
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G24‐G25
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G24‐G25 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
138
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
2,937.00 2,000.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
9,108 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.2020+
2,937.00 2,000.00
Caterpillar N/A N/A
3516C N/A N/A
eBay Inc.
G28‐G29
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G28‐G29
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G28‐G29 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 30 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
53
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
1,114.00 750.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
3,465 ‐‐
137,030
N/A N/A
60 hrs/yr/generator for non‐emergency operations.2020+
1,114.00 750.00
Caterpillar N/A N/A
C27 N/A N/A
eBay Inc.
G32‐G33
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G32‐G33
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
G32‐G33 CAT Diesel 
Generators
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
* Engineering Estimate Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 14.6*gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
6.1*
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
‐‐100.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
610*‐‐
137,030
N/A N/A
100 hrs/yr/generator for non‐emergency operations.‐‐
‐‐100.00
Caterpillar N/A N/A
D4B01369 N/A N/A
eBay Inc.
FP1
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
FP1
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
FP1 CAT Fire Pump 
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model: 2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO): bhp kWe
Proposed Site Operated Range: bhp kWe
4. Are you operating site equipment on pipeline quality natural gas? Yes No N/A
5. Are you on an interruptible gas supply? 6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel? MMscf/yr
7. Maximum Firing Rate: 8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1No. 2No. 4No. 5No. 6Other?
10. Annual Fuel Consumption: 11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content. wt.% 13. Ash Content wt.%
14. Average Firing Rate 4.5 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine: 18. Cycle
Electric Generation (Base Load) Simple Cycle
Electric Generation (Peaking) Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake‐Horsepower‐Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine‐specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low‐NOX Combustor SCR Catalyst Steam Injection
4.5
Operation
Emissions Data
‐‐*‐‐*
‐‐*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
86.00 64.00
Gas‐Firing
N/A N/A
N/A N/A
Oil‐Firing
ULSD
450 ‐‐
137,030
N/A N/A
100 hrs/yr/generator for non‐emergency operations.‐‐
86.00 64.00
John Deere N/A N/A
JU4H‐UFADJ8 N/A N/A
eBay Inc.
FP2
7/26/2023
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
FP2
7/26/2023
21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
‐‐
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal 
discharge with a note. 
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. 
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 
FP2 John Deere Fire 
Pump 
NOX
Refer to Appendix 4 
to this NOI 
application for 
detailed engine‐
specific emissions 
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO2
CH4
N2O
CO2e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total 
Stream
Air Contaminant 
Emission Rate
UTM Coordinates of 
Emission Point
(6)
Stack Sources
(7)
Height 
Above 
Ground
(ft.)
Height 
Above 
Structure
(ft.)
Exit Data
Component / 
Air Contaminant 
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307‐410‐5 using SCREEN3. 
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. 
# Confidential
X (m) Y (m)
Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack Release
Velocity (m/s)
Stack
Emission
Rate (g/s)
Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack Release
Velocity (m/s)
Stack Emission
Rate (g/s)
Engine Load
(kWe)
Stack Release
Temperature
(K)
Stack
Release
Velocity
(m/s)
Stack Emission
Rate (g/s)4
FP1 411232.8 4490852.7 1550.7 0.13 2.3 -- -- -- -- -- -- -- -- 100 779.26 26.31 1.1162E-03
G01 411271.9 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G02 411283.5 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G03 411295.4 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G04 411307.8 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G05 411319.4 4490966.2 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G06 411331.2 4490965.9 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G07 411343.2 4490965.7 1550.7 0.71 5.7 1,000 668.13 16.56 0.913 2,350 742.59 27.35 4.856 3,250 818.15 30.96 1.5251E-01
G08 411325.9 4490763.3 1550.7 0.61 8.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G09 411212.9 4490750.5 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G10 411195.0 4490755.3 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G11 411383.2 4490795.9 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G12 411383.2 4490802.0 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G13 411383.5 4490821.7 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G14 411383.5 4490828.0 1550.7 0.61 6.7 1,000 712.65 21.76 0.716 2,500 735.43 33.70 6.854 3,100 751.32 39.29 1.5957E-01
G24 411314.9 4490726.4 1550.7 0.46 6.1 650 621.38 22.02 0.555 1,750 671.04 42.25 3.709 2,500 727.98 54.07 1.2354E-01
G25 411320.7 4490726.4 1550.7 0.46 6.1 650 621.38 22.02 0.555 1,750 671.04 42.25 3.709 2,500 727.98 54.07 1.2354E-01
G26 411130.4 4490957.3 1555.5 0.46 6.1 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G27 411130.4 4490950.7 1555.5 0.46 6.1 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
FP2 411115.1 4490830.2 1555.5 0.13 10.6 -- -- -- -- -- -- -- -- 64 744.26 17.18 8.3447E-04
G15 411130.4 4490924.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 6.1094368E-02
G16 411130.5 4490917.8 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 6.1094368E-02
G17 411130.8 4490911.3 1555.5 0.46 7.2 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 7.2909E-02
G18 411130.7 4490904.9 1555.5 0.46 7.2 400 628.54 14.21 0.524 1,000 641.91 26.25 1.809 1,500 675.71 33.73 7.2909E-02
G19 411130.3 4490898.5 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G20 411130.3 4490892.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G21 411130.3 4490885.6 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G22 411130.3 4490879.2 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G23 411130.8 4490872.8 1555.5 0.46 6.7 300 632.93 4.46 0.346 700 705.98 7.63 1.336 1,000 751.21 8.93 4.4470E-02
G28 411130.4 4490970.7 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G29 411130.4 4490964.1 1555.5 0.46 8.2 550 614.18 19.14 0.608 1,400 631.43 35.78 2.618 2,000 673.21 43.96 9.6773E-02
G32 411130.8 4490944.0 1555.5 0.51 7.2 250 706.19 7.42 0.331 600 763.54 11.23 1.165 750 780.76 12.86 3.4468E-02
G33 411130.8 4490937.2 1555.5 0.51 7.2 250 706.19 7.42 0.331 600 763.54 11.23 1.165 750 780.76 12.86 3.4468E-02
Notes
1 Generator locations and release heights and stack diameters were provided by eBay. Emission rates, exhaust temperature and release velocity were retrieved from engine manufacturer spec sheets.2 Coordinates are based on NAD 1983 datum Zone 12N.
4 Annual average NO2 modeling will include all generators and parameters assuming 100% load. The emission rates are annualized assuming 100 hours per year for the fire pumps and 66 hours per year for all other generators.
Coordinates2
Elevation
(m)
Stack
Diameter
(m)
Stack
Release
Height (m)2
3 Monthly generator testing of generators G1-G7 occur 4 generators at a time while other generators occur 2 or 1 at a time. Monthly tests for all non-fire-pump engines occur for 30 minutes at a time at the engine load specified in this Table. Annual tests of all non-fire-pump generators are modeled one at a
time for a full hour at the engine load specified in this Table. All monthly and annual tests would occur between 8 a.m. and 6 p.m. Fire pump engines were not included in 1-hr NO2 modeling since emissions from these engines are small and they are unlikely to be tested simultaneously with other generators.
Generator1
Table B1
Air Model Input Parameters
eBay Data Center
South Jordan, Utah
Monthly Test Parameters3 Annual Test Parameters3
1-hr NO2 Model Inputs Annual NO2 Model Inputs
100% Engine Load (Annualized)
Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential Confidential
APPENDIX 3
GENERATOR MANUFACTURER SPECIFICATIONS AND EMISSIONS DATA
SHEETS

Appendix 3.1
G1 – G7 Specification Sheets

Page 1 of 4 3250_XC6DT2_0908
GEN-SET RATINGS
Standby
Prime
3250 ekW 60 Hz Standby
2800 ekW 60 Hz Prime
480 - 13.8kV
• EPA Tier 2 Certified
• Generator Set Tested to ISO
8528-5 for Transient Response
• CSA Listing Offered
• All gen-sets are prototype and factory tested
• MTU Onsite Energy is a single source supplier
• Global Product Support
• 2 Year Standard Warranty
• Complete Range of Accessories

20V4000 G83L Diesel Engine
• 95.4 Liter Displacement
• Common Rail Injection
• 4-Cycle
Permanent Magnet Generator (PMG)
• Brushless, Rotating Field
• 300% Short Circuit Capability
• 2/3 Pitch Windings
Digital Control Panel(s)
• UL Recognized, , NFPA 110
• Complete System Metering
• LCD Display
Cooling System
• Integral Set-mounted
• Engine Driven Fan
3250-XC6DT2
* The Generator Model Number identified in the table is for standard C Series Configuration.* The Generator Model Number identified in the table is for standard C Series Configuration.* The Generator Model Number identified in the table is for standard C Series Configuration.* The Generator Model Number identified in the table is for standard C Series Configuration. Consult the factory for alternate Consult the factory for alternate Consult the factory for alternate Consult the factory for alternate configuration.configuration.configuration.configuration.
** UL2200 Offered ** UL2200 Offered ** UL2200 Offered ** UL2200 Offered
Voltage (LVoltage (LVoltage (LVoltage (L----L)L)L)L) Phase Phase Phase Phase PFPFPFPF Hz Hz Hz Hz kWkWkWkW kVAkVAkVAkVA AMPSAMPSAMPSAMPS skVA @ 30% skVA @ 30% skVA @ 30% skVA @ 30%
voltage dip voltage dip voltage dip voltage dip
GeneratorGeneratorGeneratorGenerator
Model*Model*Model*Model* Temp RiseTemp RiseTemp RiseTemp Rise ConnectionConnectionConnectionConnection
480v 3 0.8 60 3250 4062.5 4887 C/F C/F 130°C/27°C 6 LEAD WYE
600v 3 0.8 60 3250 4062.5 3909 C/F C/F 125°C/40°C 6 LEAD WYE
4160v 3 0.8 60 3250 4062.5 564 C/F C/F 130°C/27°C 6 LEAD WYE
12470v 3 0.8 60 3200 4000 185 C/F C/F 130°C/27°C 6 LEAD WYE
13200v 3 0.8 60 3200 4000 175 C/F C/F 130°C/27°C 6 LEAD WYE
13800v 3 0.8 60 3200 4000 167 C/F C/F 130°C/27°C 6 LEAD WYE
Voltage (LVoltage (LVoltage (LVoltage (L----L)L)L)L) Phase Phase Phase Phase PFPFPFPF Hz Hz Hz Hz kWkWkWkW kVAkVAkVAkVA AMPSAMPSAMPSAMPS skVA @ 30% skVA @ 30% skVA @ 30% skVA @ 30%
voltage dip voltage dip voltage dip voltage dip
GeneratorGeneratorGeneratorGenerator
Model*Model*Model*Model* Temp RiseTemp RiseTemp RiseTemp Rise ConnectionConnectionConnectionConnection
480v 3 0.8 60 2800 3500 4210 C/F C/F 105°C/40°C 6 LEAD WYE
600v 3 0.8 60 2800 3500 3368 C/F C/F 105°C/40°C 6 LEAD WYE
4160v 3 0.8 60 2800 3500 486 C/F C/F 105°C/40°C 6 LEAD WYE
12470v 3 0.8 60 2750 3437.5 159 C/F C/F 105°C/40°C 6 LEAD WYE
13200v 3 0.8 60 2750 3437.5 150 C/F C/F 105°C/40°C 6 LEAD WYE
13800v 3 0.8 60 2750 3437.5 144 C/F C/F 105°C/40°C 6 LEAD WYE

STANDARD EQUIPMENT
ENGINE DIGITAL CONTROL PANEL(S)
GENERATOR
Page 2 of 4 3250_XC6DT2_0908
3250 ekW Diesel Gen-Set

• Air Cleaners
• Oil Pump
• Full Flow Oil Filter
• Jacket Water Pump
• Inter Cooler Water Pump
• Thermostats
• Exhaust Manifold – dry
• Blower Fan & Fan Drive
• Radiator - Unit Mounted
• Electric Starting Motor - 24V
• Governor – Electric Isochronous
• Base - Structural Steel
• SAE Flywheel & Bell Housing
• Charging Alternator - 24V
• Battery Box & Cables
• Flexible Fuel Connectors
• Flexible Exhaust Connection
• EPA Certified Engine

• NEMA MG1, IEEE and ANSI standards
compliance for temperature rise and motor
starting
• Sustained short circuit current of up to 300% of the rated current for up to 10 seconds
• Self Ventilated and Drip-proof
• Superior Voltage Waveform
• Digital, Solid State, Volts-per-hertz Regulator
• No Load to Full Load Regulation
• Brushless Alternator with Brushless Pilot Exciter
• 4 pole, Rotating Field
• 130°C Standby Temperature Rise
• 2 Bearing, Sealed
• Flexible Coupling
• Full Amortisseur Windings
• 125% Rotor Balancing
• 3-phase Voltage Sensing
• ±.25% Voltage Regulation
• 3% Maximum Harmonic Content

• Digital Metering
• Engine Parameters
• Generator Protection Functions
• Engine Protection
• SAE J1939 Engine ECU Communications
• Windows-based Software
• Multilingual Capability
• Remote Communications to our RDP-110
Remote Annunciator
• 16 Programmable Contact Inputs
• 7 contact outputs
• UL Recognized, , CE approved
• Event Recording
• IP 54 Front Panel Rating with Integrated
Gasket
• NFPA110 Level Compatible

APPLICATION DATA
Page 3 of 4 3250_XC6DT2_0908
3250 ekW Diesel Gen-Set
Liquid Capacity (Lubrication)
Fuel System
Air Requirements
Electrical
Fuel Consumption
Cooling - Radiator System
StandbyStandbyStandbyStandby PrimePrimePrimePrime
100% Power Rating: gal/hr (lit/hr).......... 237 (897)...200 (757)
75% Power Rating: gal/hr (lit/hr).......... 192 (727)...149 (564)
50% Power Rating: gal/hr (lit/hr).......... 133 (504)...103 (390)
Engine
Rated RPM:.........................................1800
Engine Governor: ................................ADEC
Max Power: Standby:Standby:Standby:Standby: bhp (kWm)..........4,678 (3,490)
Prime:Prime:Prime:Prime: bhp (kWm)..........4,035 (3,010)
Speed Regulation:................................±.25%
Frequency:..........................................60 Hz
Air Cleaner: ........................................Dry
Manufacturer:.....................MTU Detroit Diesel
Model:...............................20V4000 G83L
Type: .................................4-Cycle
Arrangement:......................20-V
Displacement: in.³ (lit)............5,822 (95.4)
Bore: in. (cm)........................6.69 (17.0)
Stoke: in. (cm).......................8.27 (21.0)
Compression Ratio: .............16.5:1
Total oil system: gal (lit)......................................103 (390)
Engine Jacket water capacity: gal (lit).................54.2 (205)
After Cooler water capacity: gal (lit) ...................14.5 (55)
System Coolant capacity: gal (lit)........................231 (873)
Electric volts DC:............................................24
Cold cranking Amps under 0°F (-17.8°C):....3,000
Fuel Supply Connection Size:............................1” NPT
Fuel Return Connection Size:.............................1” NPT
Maximum Fuel Lift: ft (m)....................................3 (1)
Recommended Fuel:..........................................Diesel #2
Total Fuel Flow: gal/hr (lit/hr)..............................349 (1,320)
StandbyStandbyStandbyStandby PrimePrimePrimePrime
Ambient Capacity
of Radiator: ºF (ºC)......................108 (42)..........108 (42)
Maximum Allowable
Static Pressure on
Radiator Exhaust: in. H20 (kPa)......0.5 (0.12).......0.5 (0.12)
Water Pump
Capacity: gal/min (lit/min)............440 (1,667).....440 (1,667)
After Cooler Pump
Capacity: gal/min (lit/min).............163 (617).......163 (617)
Heat Rejection to
Coolant: BTUM (kW).................83,030 (1,460) 67,675 (1,190)
Heat Rejection to
After Cooler: BTUM (kW)...........61,988 (1,090)..51,183 (900)
Heat Radiated to
Ambient: BTUM (kW)..................15,241 (268)...13,933 (245)
StandbyStandbyStandbyStandby PrimePrimePrimePrime
Aspirating: CFM (m3min)...........9,111 (258) ..........8,687 (246)
Air Flow Required
for Radiator Cooled
Unit: CFM (m3min)................137,228 (3,886)..137,228 (3,886)
Air Flow Required for
Heat Exchanger/
Remote Radiator based
on 25°F Rise: CFM (m3min)......29,698 (841)........27,551 (780)

Exhaust System
StandbyStandbyStandbyStandby PrimePrimePrimePrime
Gas Temp.(Stack): ºF (ºC)..........1,013 (545)........914 (490)
Gas Volume at Stack
Temp: CFM (m3min)....................26,062(738).... 22,884 (648)
Maximum Allowable
Back Pressure: in. H20 (kPa)..........34.1 (8.5)........34.1(8.5)
DISTRIBUTED BY: Materials and specifications subject to change without notice.
© MTU Onsite Energy Corporation. A Tognum Group Company.
100 Power Drive, Mankato, MN 56001
Phone: [phone]
www.mtu-online.com
Page 4 of 4 3250_XC6DT2_0908
3250 ekW Diesel Gen-Set
EMISSIONS DATA
Drawing above for illustration purposes only, based on standard open
power 480 volt generator. Lengths may vary with other voltages.
*Do Not Use for Installation Design
SOUND DATA
Standby Full LoadStandby Full LoadStandby Full LoadStandby Full Load Standby No LoadStandby No LoadStandby No LoadStandby No Load Prime Full LoadPrime Full LoadPrime Full LoadPrime Full Load Prime No LoadPrime No LoadPrime No LoadPrime No Load

23 ft (7m) OPU w/ critical grade muffler (dBA)............108........................ 100.......................106.5....................100
RATING DEFINITIONS and CONDITIONS
Weights & Dimensions
Length: in. (cm)........................ 306.38 (778)
Width: in. (cm)......................... 114.13 (290)
Height: in. (cm)........................ 130.5 (331)
Weight (dry): lb. (kg)................ 63,264 (28,696)
• Ambient capability factor at 984 ft (300m). Consult your local MTU Onsite Energy Power Generation Distributor for other
altitudes.
• Standby ratings apply to installations served by a reliable utility source. The standby rating is applicable to varying loads for
the duration of a power outage. No overload capability for this rating. Ratings are in accordance with ISO-3046/1, BS 5514,
AS 2789, and DIN 6271.
• Prime power ratings apply to installations where utility power is unavailable or unreliable. At varying load, the number of
generator set operating hours is unlimited. A 10% overload capacity is available for one hour in twelve. Ratings are in
accordance with ISO-8528/1, overload power in accordance with ISO-3046/1, BS 5514, AS 2789, and DIN 6271. For
limited running time and base load ratings, consult the factory.
• Deration Factors:
Altitude:Altitude:Altitude:Altitude: No power decrease with increased elevation up to 4,921 ft (1,500m) at 77°F (25°C); max permissible elevation is
5,905 ft (1,800m). Consult factory for altitudes between 4,921 ft (1,500m) and 5,905 ft (1,800m).
Temperature:Temperature:Temperature:Temperature: No power decrease with increased intake combustion temperature up to 107°F (42°C) at 328 ft (100m).
Consult factory for performance at higher temperatures.
NOx + NMHCNOx + NMHCNOx + NMHCNOx + NMHC COCOCOCO PMPMPMPM
4.19..............................0.82 .................0.14

All units are in g/hp-hr and are EPA D2 cycle values.

Emission levels of the engine may vary as a function of ambient temperature, barometric pressure, humidity, fuel type and quality, installation parameters, measur-
ing instrumentation, etc. The data provided are laboratory results from one engine representing this rating. The data was obtained under controlled environ-
mental conditions with calibrated instrumentation traceable to the United States National Bureau of Standards and in compliance with US EPA regulations found
within 40 CFR Part 89. The weighted cycle value from each engine is guaranteed to be below the US EPA Standards at the US EPA defined conditions.

Appendix 3.2
G8 – G14 Specification Sheets



  
 
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Appendix 3.3
G15 – G16, G19-G22, and G26-31 Specification Sheets

Specifications
Generator Set Specifications
Minimum Rating 1650 ekW (2500 kVA)
Maximum Rating 2500 ekW (2750 kVA)
Voltage 480 volts
Frequency 60 Hz
Speed 1800 RPM
Generator Set Configurations
Emissions/Fuel Strategy
U.S. EPA Certified for Stationary Emergency Use Only (Tier
2 Nonroad Equivalent Emission Standards), Low Fuel
Consumption
Engine Specifications
Engine Model 3516C, ATAAC, V-16,4-Stroke Water-Cooled Diesel
Compression Ratio 14.7:1
Aspiration TA
Governor Type Adem™3
Fuel System Electronic unit injection
Bore 170 mm 6.69 in
Stroke (Std)190 mm 7.48 in
Stroke (HD)215 mm 8.46 in
Caterpillar is leading the power generation marketplace
with Power Solutions engineered to deliver unmatched
flexibility, expandability, reliability, and cost-effectiveness.
Page: M-1 of M-4© 2015 Caterpillar All Rights ReservedMSS-EPG-18331919-003.pdf
3516C Generator Set
Electric Power
SS-10052989-18331919-006 SS Page 1 of 7
Benefits And Features
Cat Diesel Engine
•Reliable, rugged, durable design
•Field-proven in thousands of applications worldwide
•Four-stroke-cycle diesel engine combines consistent performance and excellent fuel economy with
minimum weight
Generator
•Matched to the performance and output characteristics of Cat engines
•Industry leading mechanical and electrical design
•Industry leading motor starting capabilities
•High Efficiency
Cat EMCP Control Panel
The EMCP controller features the reliability and durability you have come to expect from your Cat equipment.
EMCP4 is a scalable control platform designed to ensure reliable generator set operation, providing extensive
information about power output and engine operation. EMCP4 systems can be further customized to meet your
needs through programming and expansion modules.
Seismic Certification
•Seismic Certification available.
•Anchoring details are site specific, and are dependent on many factors such as generator set size, weight,
and concrete strength.
•IBC Certification requires that the anchoring system used is reviewed and approved by a Professional
Engineer
•Seismic Certification per Applicable Building Codes: IBC 2000, IBC 2003, IBC 2006, IBC 2009, CBC
2007, CBC 2010
•Pre-approved by OSHPD and carries an OSP-0321-10 for use in healthcare projects in California
Design Criteria
The generator set accepts 100% rated load in one step per NFPA 110 and meets ISO 8528-5 transient
response.
UL 2200 / CSA - Optional
•UL 2200 listed packages
•CSA Certified
•Certain restrictions may apply.
•Consult with your Cat® Dealer.
Single-Source Supplier
Fully prototype tested with certified torsional vibration analysis available
Page: M-2 of M-4© 2015 Caterpillar All Rights ReservedMSS-EPG-18331919-003.pdf
3516C Generator Set
Electric Power
SS-10052989-18331919-006 SS Page 2 of 7
World Wide Product Support
Cat Dealers provide extensive post sale support including maintenance and repair agreements. Cat dealers have
over 1,800 dealer branch stores operating in 200 countries. The Cat® SOSSM program cost effectively detects
internal engine component condition, even the presence of unwanted fluids and combustion by-products.
Standard Equipment
Air Inlet
•Air Cleaner
Cooling
•Package mounted radiator
Exhaust
•Exhaust flange outlet
Fuel
•Primary fuel filter with integral water separator
•Secondary fuel filter
•Fuel priming pump
Generator
•Matched to the performance and output characteristics of Cat engines
•IP23 Protection
Power Termination
•Bus Bar
Control Panel
•EMCP 4 Genset Controller
General
•Paint - Caterpillar Yellow except rails and radiators gloss black
Optional Equipment
Exhaust
•Exhaust mufflers
Page: M-3 of M-4© 2015 Caterpillar All Rights ReservedMSS-EPG-18331919-003.pdf
3516C Generator Set
Electric Power
SS-10052989-18331919-006 SS Page 3 of 7
The International System of Units (SI) is used in this publication. CAT, CATERPILLAR, their
respective logos, ADEM, EUI, S•O•S, "Caterpillar Yellow" and the "Power Edge" trade dress, as well
as corporate and product identity used herein, are trademarks of Caterpillar and may not be used
without permission.
Generator
•Anti-condensation heater
•Excitation: [ ] Permanent Magnet Excited (PM) [ ] Internally Excited (IE)
•Oversize and premium generators
Power Termination
•Circuit breakers, UL listed
•Circuit breakers, IEC compliant
Control Panels
•EMCP (4.2) (4.3) (4.4)
•Generator temperature monitoring & protection
•Load share module
•Digital I/O module
•Remote monitoring software
Mounting
•Rubber anti-vibration mounts
•Spring-type vibration isolator
•IBC isolators
Starting/Charging
•Battery chargers
•Oversize batteries
•Jacket water heater
•Heavy-duty starting system
•Charging alternator
•Air starting motor with control and silencer
General
•The following options are based on regional and product configuration:
•Seismic Certification per applicable building codes: IBC 2000, IBC 2003, IBC 2006, IBC 2009, CBC 2007
•UL 2200 package
•EU Certificate of Conformance (CE)
•CSA Certification
•EEC Declaration of Conformity
•Enclosures: sound attenuated, weather protective
•Automatic transfer switches (ATS)
•Integral & sub-base fuel tanks
•Integral & sub-base UL listed dual wall fuel tanks
Page: M-4 of M-4© 2015 Caterpillar All Rights ReservedMSS-EPG-18331919-003.pdf
3516C Generator Set
Electric Power
SS-10052989-18331919-006 SS Page 4 of 7
3516C
2000 ekW/ 2500 kVA
60 Hz/ 1800 rpm/ 480 V
Image shown may not reflect actual configuration
Metric English
Package Performance
Genset Power Rating with Fan @ 0.8 Power Factor 2000 ekW
Genset Power Rating 2500 kVA
Aftercooler (Separate Circuit)N/A N/A
Fuel Consumption
100% Load with Fan 522.5 L/hr 138.0 gal/hr
75% Load with Fan 406.8 L/hr 107.5 gal/hr
50% Load with Fan 293.6 L/hr 77.5 gal/hr
25% Load with Fan 169.7 L/hr 44.8 gal/hr
Cooling System¹
Engine Coolant Capacity 233.0 L 61.6 gal
Inlet Air
Combustion Air Inlet Flow Rate 185.5 m³/min 6548.9 cfm
Max. Allowable Combustion Air Inlet Temp 50 ° C 121 ° F
Exhaust System
Exhaust Stack Gas Temperature 400.1 ° C 752.1 ° F
Exhaust Gas Flow Rate 433.1 m³/min 15292.8 cfm
Exhaust System Backpressure (Maximum Allowable)6.7 kPa 27.0 in. water
TSS-DM8263-04-GS-EPG-10052989.pdf © 2016 Caterpillar All Rights Reserved Page 1 of 3
ELECTRIC POWER - Technical Spec Sheet
STANDARD
3516C
2000 ekW/ 2500 kVA/ 60 Hz/ 1800 rpm/ 480 V/ 0.8 Power Factor
Rating Type: STANDBY Emissions: U.S. EPA Stationary Emergency Use Only
SS-10052989-18331919-006 SS Page 5 of 7
DEFINITIONS AND CONDITIONS
1. For ambient and altitude capabilities consult your Cat dealer. Air flow restriction (system) is added to existing
restriction from factory.
2. UL 2200 Listed packages may have oversized generators with a different temperature rise and motor starting
characteristics. Generator temperature rise is based on a 40° C ambient per NEMA MG1-32.
3. Emissions data measurement procedures are consistent with those described in EPA CFR 40 Part 89, Subpart D &
E and ISO8178-1 for measuring HC, CO, PM, NOx. Data shown is based on steady state operating conditions of
77° F, 28.42 in HG and number 2 diesel fuel with 35° API and LHV of 18,390 btu/lb. The nominal emissions data
shown is subject to instrumentation, measurement, facility and engine to engine variations. Emissions data is based
on 100% load and thus cannot be used to compare to EPA regulations which use values based on a weighted cycle.
Heat Rejection
Heat Rejection to Jacket Water 759 kW 43150 Btu/min
Heat Rejection to Exhaust (Total)1788 kW 101696 Btu/min
Heat Rejection to Aftercooler 672 kW 38240 Btu/min
Heat Rejection to Atmosphere from Engine 133 kW 7564 Btu/min
Heat Rejection to Atmosphere from Generator 96 kW 5482 Btu/min
Alternator²
Motor Starting Capability @ 30% Voltage Dip 5925 skVA
Current 3007 amps
Frame Size 1625
Excitation IE
Temperature Rise 125 ° C
Emissions (Nominal)³
NOx 2754.3 mg/Nm³5.5 g/hp-hr
CO 143.3 mg/Nm³0.3 g/hp-hr
HC 44.7 mg/Nm³0.1 g/hp-hr
PM 10.4 mg/Nm³0.0 g/hp-hr
TSS-DM8263-04-GS-EPG-10052989.pdf © 2016 Caterpillar All Rights Reserved Page 2 of 3
ELECTRIC POWER - Technical Spec Sheet
STANDARD
3516C
2000 ekW/ 2500 kVA/ 60 Hz/ 1800 rpm/ 480 V/ 0.8 Power Factor
Rating Type: STANDBY Emissions: U.S. EPA Stationary Emergency Use Only
SS-10052989-18331919-006 SS Page 6 of 7
Applicable Codes and Standards:
AS1359, CSA C22.2 No100-04, UL142,UL489, UL869, UL2200,
NFPA37, NFPA70, NFPA99, NFPA110, IBC, IEC60034-1, ISO3046, ISO8528,
NEMA MG1-22,NEMA MG1-33, 2006/95/EC, 2006/42/EC, 2004/108/EC.
Note: Codes may not be available in all model configurations. Please consult your local Cat Dealer representative for
availability.
Ratings are based on SAE J1349 standard conditions. These ratings also apply at ISO3046 standard conditions
Fuel Rates are based on fuel oil of 35º API [16º C (60º F)] gravity having an LHV of 42 780 kJ/kg (18,390 Btu/lb) when
used at 29º C (85º F) and weighing 838.9 g/liter (7.001 lbs/U.S. gal.). Additional ratings may be available for specific
customer requirements, contact your Cat representative for details. For information regarding Low Sulfur fuel and
Biodiesel capability, please consult your Cat dealer.
www.Cat-ElectricPower.com
STANDBY:Output available with varying load for the duration of the interruption of the normal source power. Average
power output is 70% of the standby power rating. Typical operation is 200 hours per year, with maximum expected usage
of 500 hours per year.
The International System of Units (SI) is used in this publication. CAT, CATERPILLAR, their respective
logos, ADEM, EUI, S•O•S, "Caterpillar Yellow" and the "Power Edge" trade dress, as well as corporate
and product identity used herein, are trademarks of Caterpillar and may not be used without permission.
Performance No.: DM8263-04
Feature Code: 516DEA9
Generator Arrangement: 2523854
Source Country: U.S.
Date: 07/05/2016
TSS-DM8263-04-GS-EPG-10052989.pdf © 2016 Caterpillar All Rights Reserved Page 3 of 3
ELECTRIC POWER - Technical Spec Sheet
STANDARD
3516C
2000 ekW/ 2500 kVA/ 60 Hz/ 1800 rpm/ 480 V/ 0.8 Power Factor
Rating Type: STANDBY Emissions: U.S. EPA Stationary Emergency Use Only
SS-10052989-18331919-006 SS Page 7 of 7
GENERATOR SET PACKAGE
PERFORMANCE DATA


  
 
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Appendix 3.5
FP1 Specification Sheet

Emissions Information CAT D4B01369 100 kW Genset

According to our record the Engine Serial No: E5M01465 which is installed in Genset Serial
No:D4B01369 has the following Emission data values as shown in the screenshot.

Regards
Engine Certification 1
Disclaimer: The information provided has been compiled from sources believed to be reliable and is
accurate to the best of Caterpillar's knowledge; however, Caterpillar does not guarantee the
accuracy, completeness, and validity of the information and cannot be held liable for any errors or
omissions. All information provided should be independently verified and confirmed, and you should
not rely solely upon the information provided. One potential method to independently verify the
information provided is to examine the emissions label located on the engine.

Appendix 3.6
FP2 Specification Sheet

Appendix 3.7
G23 Specification Sheet



  
 
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Appendix 3.8
G24 – G25 Specification Sheets

Standard Features
Standby
60 Hz ekW (kVA)
Mission Critical
60 Hz ekW (kVA)
Prime
60 Hz ekW (kVA)
Continuous
60 Hz ekW (kVA)Emissions Performance
2500 (3125)2500 (3125)2250 (2812)2050 (2562)U.S. EPA Stationary EmergencyUse Only (Tier 2)
Image shown may not reflect actual configuration
Bore – mm (in)170 (6.69)
Stroke – mm (in)215 (8.46)
Displacement – L (in3)78 (4764.73)
Compression Ratio 14.7:1
Aspiration TA
Fuel System EUI
Governor Type ADEM™ A3
Cat® Diesel Engine
• Meets U.S. EPA Stationary Emergency Use
Only (Tier 2) emission standards
• Reliable performance proven in thousands of
applications worldwide
Generator Set Package
• Accepts 100% block load in one step and meets
other NFPA 110 loading requirements
• Conforms to ISO 8528-5 G3 load acceptance
requirements
• Reliability verified through torsional vibration,
fuel consumption, oil consumption, transient
performance, and endurance testing
Alternators
• Superior motor starting capability minimizes
need for oversizing generator
• Designed to match performance and output
characteristics of Cat diesel engines
Cooling System
• Cooling systems available to operate in ambient
temperatures up to 50°C (122°F)
• Tested to ensure proper generator set cooling
EMCP 4 Control Panels
• User-friendly interface and navigation
• Scalable system to meet a wide range of
installation requirements
• Expansion modules and site specific
programming for specific customer requirements
Warranty
• 24 months/1000-hour warranty for standby and
mission critical ratings
• 12 months/unlimited hour warranty for prime
and continuous ratings
• Extended service protection is available to
provide extended coverage options
Worldwide Product Support
• Cat dealers have over 1,800 dealer branch
stores operating in 200 countries
• Your local Cat dealer provides extensive
post-sale support, including maintenance and
repair agreements
Financing
• Caterpillar offers an array of financial products
to help you succeed through financial service
excellence
• Options include loans, finance lease,
operating lease, working capital, and revolving
line of credit
• Contact your local Cat dealer for availability in
your region
Cat® 3516C
Diesel Generator Sets
LEHE1377-00 Page 1 of 4
3516C Diesel Generator Sets
Electric Power
LEHE1377-00 Page 2 of 4
Optional Equipment
Note: Some options may not be available on all models. Certifications may not be available with all model configurations. Consult factory for availability.
Engine
Air Cleaner
 Single element
 Dual element
Muffler
 Industrial grade (15 dB)
Starting
 Standard batteries
 Oversized batteries
 Standard electric starter(s)
 Heavy duty electric starter(s)
 Air starter(s)
 Jacket water heater
Alternator
Output voltage
 380V  6300V
 440V  6600V
 480V  6900V
 600V  12470V
 2400V  13200V
 4160V  13800V
Temperature Rise
(over 40°C ambient)
 150°C
 125°C/130°C
 105°C
 80°C
Winding type
 Random wound
 Form wound
Excitation
 Internal excitation (IE)
 Permanent magnet (PM)
Attachments
 Anti-condensation heater
 Stator and bearing temperature
monitoring and protection
Power Termination
Type
 Bus bar
 Circuit breaker
 1600A  2000A
 2500A  3000A
 3200A  4000A
 5000A
 IEC  UL
 3-pole  4-pole
 Manually operated
 Electrically operated
Trip Unit
 LSI  LSI-G
 LSIG-P
Control System
Controller
 EMCP 4.2B
 EMCP 4.3
 EMCP 4.4
Attachments
 Local annunciator module
 Remote annunciator module
 Expansion I/O module
 Remote monitoring software
Charging
 Battery charger – 10A
 Battery charger – 20A
 Battery charger – 35A
Vibration Isolators
 Rubber
 Spring
 Seismic rated
Cat Connect
Connectivity
 Ethernet
 Cellular
 Satellite
Extended Service Options
Terms
 2 year (prime)
 3 year
 5 year
 10 year
Coverage
 Silver
 Gold
 Platinum
 Platinum Plus
Ancillary Equipment
 Automatic transfer switch
(ATS)
 Uninterruptible power supply
(UPS)
 Paralleling switchgear
 Paralleling controls
Certifications
 UL2200
 CSA
 IBC seismic certification
 OSHPD pre-approval
2
3516C Diesel Generator Sets
Electric Power
LEHE1377-00 Page 3 of 4
Package Performance
Performance Standby Mission Critical Prime Continuous
Frequency 60 Hz 60 Hz 60 Hz 60 Hz
Gen set power rating with fan 2500 ekW 2500 ekW 2250 ekW 2050 ekW
Gen set power rating with fan @
0.8 power factor 3125 kVA 3125 kVA 2812 kVA 2562 kVA
Emissions EPA ESE (TIER 2)EPA ESE (TIER 2)EPA ESE (TIER 2)EPA ESE (TIER 2)
Performance number EM1894-01 EM1895-02 DM8447-04 DM8268-03
Fuel Consumption
100% load with fan – L/hr (gal/hr)656.8 (175.3)656.8 (175.3)593.0 (156.6)549.3 (145.1)
75% load with fan – L/hr (gal/hr)510.8 (134.9)510.8 (134.9)467.8 (123.6)435.6 (115.1)
50% load with fan – L/hr (gal/hr)372.4 (98.4)372.4 (98.4)341.9 (90.3)316.8 (83.7)
25% load with fan – L/hr (gal/hr)219.3 (57.9)219.3 (57.9)203.0 (53.6)188.9 (49.9)
Cooling System
Radiator air flow restriction (system) –
kPa (in. water)0.12 (0.48)0.12 (0.48)0.12 (0.48)0.12 (0.48)
Radiator air flow – m3/min (cfm)2800.0 (98881)2800.0 (98881)2800.0 (98881)2800.0 (98881)
Engine coolant capacity – L (gal)233.0 (61.6)233.0 (61.6)233.0 (61.6)233.0 (61.6)
Radiator coolant capacity – L (gal)268.8 (71.0)268.8 (71.0)268.8 (71.0)268.8 (71.0)
Total coolant capacity – L (gal)501.8 (132.6)501.8 (132.6)501.8 (132.6)501.8 (132.6)
Inlet Air
Combustion air inlet flow rate – m3/min (cfm)242.2 (7212.2)242.2 (7212.2)193.1 (6819.8)183.8 (6491.7)
Exhaust System
Exhaust stack gas temperature – °C (°F)490.7 (915.2)490.7 (915.2)471.3 (880.4)463.6 (866.5)
Exhaust gas flow rate – m3/min (cfm)554.5 (19578.8)554.5 (19578.8)507.9 (17935.1)476.5 (16826.7)
Exhaust system backpressure
(maximum allowable) – kPa (in. water)6.7 (27.0)6.7 (27.0)6.7 (27.0)6.7 (27.0)
Heat Rejection
Heat rejection to jacket water – kW (Btu/min)826 (46992)826 (46992)777 (44160)739 (42021)
Heat rejection to exhaust (total) – kW (Btu/min)2502 (142265)2502 (142265)2243 (127532)2092 (118949)
Heat rejection to aftercooler – kW (Btu/min)786 (44723)786 (44723)690 (39224)619 (35176)
Heat rejection to atmosphere from engine –
kW (Btu/min)161 (9146)161 (9146)150 (8542)145 (8229)
Heat rejection from alternator – kW (Btu/min)121 (6853)121 (6853)99 (5607)94 (5368)
Emissions (Nominal)
NOx mg/Nm3 (g/hp-h)2349.1 (5.32)2349.1 (5.32)2206.7 (4.95)2038.1 (4.62)
CO mg/Nm3 (g/hp-h)195.4 (0.42)195.4 (0.42)141.2 (0.30)124.8 (0.27)
HC mg/Nm3 (g/hp-h)42.1 (0.10)42.1 (0.10)44.4 (0.11)49.2 (0.12)
PM mg/Nm3 (g/hp-h)14.1 (0.04)14.1 (0.04)10.9 (0.03)11.0 (0.03)
Emissions (Potential Site Variation)
NOx mg/Nm3 (g/hp-h)2818.9 (6.38)2818.9 (6.38)2648.0 (5.94)2445.8 (5.55)
CO mg/Nm3 (g/hp-h)351.8 (0.76)351.8 (0.76)254.2 (0.55)224.6 (0.49)
HC mg/Nm3 (g/hp-h)55.9 (0.14)55.9 (0.14)59.1 (0.15)65.5 (0.16)
PM mg/Nm3 (g/hp-h)19.7 (0.05)19.7 (0.05)15.2 (0.04)15.3 (0.04)
3516C Diesel Generator Sets
Electric Power
Weights and Dimensions
Dim “A”
mm (in)
Dim “B”
mm (in)
Dim “C”
mm (in)
Dry Weight
kg (lb)
7495 (295.1)2569 (101.2)3009 (118.5)17 590 (38,780)
Note: For reference only. Do not use for installation design. Contact your local Cat dealer for precise weights and dimensions.
Ratings Definition
StandbyOutput available with varying load for the duration of the interruption of the normal source power. Average power output is 70% of the standby power rating. Typical operation is 200 hours per year, with maximum expected usage of 500 hours per year.
Mission CriticalOutput available with varying load for the duration of the interruption of the normal source power. Average power output is 85% of the mission critical power rating. Typical peak demand up to 100% of rated power for up to 5% of the operating time. Typical operation is 200 hours per year, with maximum expected usage of 500 hours per year.
PrimeOutput available with varying load for an unlimited time. Average power output is 70% of the prime power rating. Typical peak demand is 100% of prime rated ekW with 10% overload capability for emergency use for a maximum of 1 hour in 12. Overload operation cannot exceed 25 hours per year.
ContinuousOutput available with non-varying load for an unlimited time. Average power output is 70-100% of the continuous power rating. Typical peak demand is 100% of continuous rated kW for 100% of the operating hours.
Applicable Codes and StandardsAS1359, CSA C22.2 No100-04, UL142, UL489, UL869, UL2200, NFPA37, NFPA70, NFPA99, NFPA110, IBC, IEC60034-1, ISO3046, ISO8528, NEMA MG1-22, NEMA MG1-33, 2014/35/EU, 2006/42/EC, 2014/30/EU.
Note: Codes may not be available in all model configurations. Please consult your local Cat dealer for availability.
Data Center ApplicationsTier III/Tier IV compliant per Uptime Institute
requirements. ANSI/TIA-942 compliant for Rated-1
through Rated-4 data centers.
Fuel Rates
Fuel rates are based on fuel oil of 35º API [16°C (60ºF)]
gravity having an LHV of 42,780 kJ/kg (18,390 Btu/lb)
when used at 29ºC (85ºF) and weighing 838.9 g/liter
(7.001 lbs/U.S. gal.)
www.cat.com/electricpower
©2017 CaterpillarAll rights reserved.
Materials and specifications are subject to change without notice. The International System of Units (SI) is used in this publication.
CAT, CATERPILLAR, their respective logos, ADEM, “Caterpillar Yellow”, the “Power Edge” trade dress as well as corporate and product identity used herein, are trademarks of Caterpillar and may not be used without permission.

3516 PGFL
LEHE1377-00 (8-17)
A B
C
FINAL DIMENSIONS
INCLUDED IN ENCLOSURE
PACKAGE
ENGINE PERFORMANCE DATA


  
  
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Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential
APPENDIX 4
POTENTIAL EMISSIONS CALCULATIONS
Table 1
Facility-Wide Potential Emissions
Existing Emergency Generators Cooling Towers
NOX 49.94 --49.94 70 No
CO 5.89 --5.89 100 No
VOC 1.15 --1.15 50 No
PM 0.63 3.04 3.67 100 No
PM10 0.63 2.29 2.92 100 No
PM2.5 0.63 6.84E-03 0.64 70 No
SO2 0.056 --0.056 70 No
Maximum Individual
HAP (Benzene)0.0048 --0.0048 10 No
Total HAP 0.036 --0.036 25 No
CO2e 3,677.73 --3677.73 ----
Notes:
1.
2.
3.Utah Administrative Code. R307-403. Permit: New and Modified Sources in Nonattainment Areas and Maintenance Areas.
https://rules.utah.gov/publicat/code/r307/r307-403.htm#E2.
UAC R307-420 applies when Salt Lake County is designated as a maintenance area with respect to the 2015 8-hr Ozone National
Ambient Air Quality Standard (NAAQS). Salt Lake County is currently classified as Marginal nonattainment for the Ozone standard.
However, UAC does not have regulations codified for when Salt Lake County is designated as nonattainment, and therefore, the Major Source classification for VOC from UAC R307-420 was used.
Refer to the definition of "Major Source" found in Rule R307-101 of the Utah Administrative Code. The Major Source thresholds for
NOX, VOC, PM10, PM2.5, and SO2 have been set in Rule R307-420 in accordance with the severity of the surrounding nonattainment areas consistent with the relevant section of the Clean Air Act. Please note, in some cases these pollutants are regulated as precursor
pollutants to the pollutant for which Salt Lake County has been designated with "nonattainment" status.
Pollutant Above Threshold?
Title V Major Source
Threshold2,3
(tpy)
Facility-Wide Potential
Annual Emissions
(tpy)
Potential Annual Emissions1
(tpy)
# Confidential
Generators G1-G22, G26-G27
1 Number of Generator Engines
G1-G7 (3.25 MW) Engines 7
G8-G14 (3.1 MW) Engines 7
2
6
G17-G18 (1.5 MW) Engines 2
2 Power Output by Load
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
G1-G7 -- -- -- -- -- 349.0 872.0 1,745.0 2,618.0 3,490.0
G8-G14 438.0 1,094.0 2,188.0 3,282.0 4,376.0 -- -- -- -- --
G15-G16; G19-G22; G26-
G27 411.0 839.0 1,521.0 2,212.0 2,937.0 -- -- -- -- --
G17-G18 312.0 632.0 1,144.0 1,662.0 2,206.0 -- -- -- -- --
Notes:
1.
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
G1-G7 -- -- 133.0 192.0 237.0 3.28 8.19 16.38 24.58 32.76
G8-G14 37.4 75.0 125.1 159.8 210.7 5.12 10.28 17.14 21.90 28.87
G15-G16; G19-G22; G26-
G27 26.4 44.8 77.5 107.5 138.0 3.62 6.14 10.62 14.73 18.91
G17-G18 19.7 33.9 58.0 82.0 104.6 2.70 4.65 7.95 11.24 14.33
Notes:
1.
2.
7,000 Btu/hp-hr
1.341 hp/kWm
3.
Diesel HHV =0.137 MMBtu/gal
Per the manufacturer specification sheets and performance data for each engine model.
Engines Group Power Output (bhp/engine) 1 Power Output (kWm/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
Heat Input
(MMBtu/hr/engine) 2,3
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
G1-G7 diesel fuel consumption was not available from manufacturer specification sheets. Heat Input was calculated using conversion factors from USEPA's AP-42,
Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, Table 3.4-1, footnote e (October 1996) and Appendix-A:
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All
Stationary Dual-fuel Engines, Table 3.4-1, footnote a (October 1996):
G19-G22; G26-G27 (2.0 MW) Engines
G15-G16 (2.0 MW) Engines
# Confidential
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
NOX -- 6.20 6.00 7.00 8.70 8.18 3.22 3.85 6.28 7.26
CO -- 3.80 1.70 1.20 1.30 4.17 1.66 0.78 1.03 0.63
VOC2 -- 0.90 0.55 0.32 0.23 0.75 0.35 0.17 0.06 0.05
Filterable PM3 -- 0.44 0.210 0.090 0.070 0.29 0.12 0.06 0.05 0.04
Notes:
1.
2.
3.
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
NOX 7.13 5.03 3.82 4.67 6.56 9.14 5.85 4.26 4.41 6.58
CO 4.36 2.11 0.59 0.39 0.54 6.13 3.13 1.47 0.71 0.87
VOC2 1.08 0.49 0.34 0.23 0.14 1.06 0.45 0.32 0.23 0.16
Filterable PM3 0.49 0.31 0.080 0.040 0.040 0.36 0.29 0.13 0.06 0.04
Notes:
1.
2.
3.
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated
Speed Potential Site Variation" (i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Pollutant
Uncontrolled Emission Factors for G15-G16; G19-G22; G26-
G27 Engines (g/bhp-hr) 1
Uncontrolled Emission Factors for G17-G18 Engines
(g/bhp-hr) 1
Pollutant
Uncontrolled Emission Factors for G1-G7 Engines
(g/kW-hr) 1
Uncontrolled Emission Factors for G8-G14 Engines
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated
Speed Potential Site Variation" (i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
# Confidential
3 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.PAH = Polycyclic Aromatic Hydrocarbons
2 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
Pollutant Emission Factor
(lb/MMBtu)1
2.12E-04
7.88E-06
2.52E-05Acetaldehyde
Acrolein
Total PAH3
SO22
Condensable PM
Benzene
Toluene
Xylenes
Formaldehyde 7.89E-05
1.93E-04
2.81E-04
7.76E-04
7.70E-03
1.52E-03
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
Pollutant Emission Factor
(lb/MMBtu)1
163.61
1.32E-03
6.61E-03
163.05
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
# Confidential
4 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum
Criteria Pollutants
NOX -- 11.92 23.08 40.40 66.94 66.94 7.90 7.77 18.57 45.44 70.04 70.04
CO -- 7.31 6.54 6.93 10.00 10.00 4.03 4.00 3.76 7.45 6.08 7.45
VOC -- 1.73 2.12 1.85 1.77 2.12 0.72 0.84 0.82 0.43 0.48 0.84
PM/PM10/PM2.54 -- 0.91 0.93 0.71 0.79 0.93 0.32 0.37 0.42 0.53 0.61 0.61
SO2 -- 0.012 0.025 0.037 0.050 0.050 0.008 0.016 0.026 0.033 0.044 0.044
Hazardous Air Pollutants
Benzene 2.54E-03 6.35E-03 1.27E-02 1.91E-02 2.54E-02 2.54E-02 3.98E-03 7.98E-03 1.33E-02 1.70E-02 2.24E-02 2.24E-02
Toluene 9.21E-04 2.30E-03 4.60E-03 6.91E-03 9.21E-03 9.21E-03 1.44E-03 2.89E-03 4.82E-03 6.15E-03 8.11E-03 8.11E-03
Xylenes 6.32E-04 1.58E-03 3.16E-03 4.74E-03 6.32E-03 6.32E-03 9.89E-04 1.98E-03 3.31E-03 4.23E-03 5.57E-03 5.57E-03
Formaldehyde 2.58E-04 6.46E-04 1.29E-03 1.94E-03 2.58E-03 2.58E-03 4.04E-04 8.11E-04 1.35E-03 1.73E-03 2.28E-03 2.28E-03
Acetaldehyde 8.26E-05 2.06E-04 4.13E-04 6.19E-04 8.26E-04 8.26E-04 1.29E-04 2.59E-04 4.32E-04 5.52E-04 7.28E-04 7.28E-04
Acrolein 2.58E-05 6.45E-05 1.29E-04 1.94E-04 2.58E-04 2.58E-04 4.04E-05 8.10E-05 1.35E-04 1.73E-04 2.28E-04 2.28E-04
Total PAH 6.95E-04 1.74E-03 3.47E-03 5.21E-03 6.95E-03 6.95E-03 1.09E-03 2.18E-03 3.63E-03 4.64E-03 6.12E-03 6.12E-03
Total HAP 5.16E-03 1.29E-02 2.58E-02 3.87E-02 5.16E-02 5.16E-02 8.07E-03 1.62E-02 2.70E-02 3.45E-02 4.54E-02 4.54E-02
Greenhouse Gases
CO2 534.17 1,334.67 2,670.87 4,007.08 5,341.75 5,341.75 835.64 1,675.75 2,795.14 3,570.46 4,707.73 4,707.73
CH4 0.02 0.05 0.11 0.16 0.22 0.22 0.03 0.07 0.11 0.14 0.19 0.19
N2O 0.00 0.01 0.02 0.03 0.04 0.04 0.007 0.014 0.023 0.029 0.038 0.04
CO2e 536.01 1,339.25 2,680.04 4,020.83 5,360.08 5,360.08 838.51 1,681.50 2,804.74 3,582.71 4,723.88 4,723.88
Notes:
1.
2.
3.
4.
G8-G14 Engines - Hourly Emissions
(lb/hr/engine) 2, 3
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/gen) = Emission Factor at Load X (g/kWm-hr) x Engine Power at Load X (kWm/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
Pollutant
G1-G7 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
# Confidential
4 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX 6.46 9.30 12.81 22.77 42.48 42.48 6.29 8.15 10.74 16.16 32.00 32.00
CO 3.95 3.90 1.98 1.90 3.50 3.95 4.22 4.36 3.71 2.60 4.23 4.36
VOC 0.98 0.91 1.14 1.12 0.91 1.14 0.73 0.63 0.81 0.84 0.78 0.84
PM/PM10/PM2.54 0.47 0.62 0.35 0.31 0.40 0.62 0.27 0.44 0.39 0.31 0.30 0.44
SO2 0.005 0.009 0.016 0.022 0.029 0.029 0.004 0.007 0.012 0.017 0.022 0.022
Hazardous Air Pollutants
Benzene 2.81E-03 4.76E-03 8.24E-03 1.14E-02 1.47E-02 1.47E-02 2.09E-03 3.60E-03 6.17E-03 8.72E-03 1.11E-02 1.11E-02
Toluene 1.02E-03 1.73E-03 2.98E-03 4.14E-03 5.31E-03 5.31E-03 7.59E-04 1.31E-03 2.23E-03 3.16E-03 4.03E-03 4.03E-03
Xylenes 6.98E-04 1.18E-03 2.05E-03 2.84E-03 3.65E-03 3.65E-03 5.21E-04 8.97E-04 1.53E-03 2.17E-03 2.77E-03 2.77E-03
Formaldehyde 2.85E-04 4.84E-04 8.38E-04 1.16E-03 1.49E-03 1.49E-03 2.13E-04 3.67E-04 6.27E-04 8.87E-04 1.13E-03 1.13E-03
Acetaldehyde 9.12E-05 1.55E-04 2.68E-04 3.71E-04 4.77E-04 4.77E-04 6.80E-05 1.17E-04 2.00E-04 2.83E-04 3.61E-04 3.61E-04
Acrolein 2.85E-05 4.84E-05 8.37E-05 1.16E-04 1.49E-04 1.49E-04 2.13E-05 3.66E-05 6.26E-05 8.85E-05 1.13E-04 1.13E-04
Total PAH 7.67E-04 1.30E-03 2.25E-03 3.12E-03 4.01E-03 4.01E-03 5.72E-04 9.85E-04 1.68E-03 2.38E-03 3.04E-03 3.04E-03
Total HAP 5.69E-03 9.66E-03 1.67E-02 2.32E-02 2.98E-02 2.98E-02 4.25E-03 7.31E-03 1.25E-02 1.77E-02 2.26E-02 2.26E-02
Greenhouse Gases
CO2 589.86 1,000.98 1,731.60 2,401.90 3,083.37 3,083.37 440.16 757.44 1,295.91 1,832.15 2,337.11 2,337.11
CH4 0.02 0.04 0.07 0.10 0.13 0.13 0.02 0.03 0.05 0.07 0.09 0.09
N2O 0.005 0.008 0.014 0.019 0.025 0.03 0.004 0.006 0.011 0.015 0.019 0.02
CO2e 591.89 1,004.41 1,737.55 2,410.14 3,093.95 3,093.95 441.67 760.04 1,300.36 1,838.44 2,345.13 2,345.13
Notes:
1.
2.
3.Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
Pollutant
G15-G16; G19-G22; G26-G27 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
G17-G18 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
# Confidential
5 Potential to Emit - All Pollutants
Pollutant
Maximum Engine
Operation
(hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.5
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
308.34
2.98E-03
4.01E-04
1.49E-05
4.77E-05
1.49E-04
Potential Annual
Emissions G1-G7
(tpy)
Potential Annual
Emissions G8-G14
(tpy)
Potential Annual
Emissions G15-G16
(tpy)
Potential Annual
Emissions G19-G22;
G26-27
(tpy)
60 60 100 60
Potential Annual
Emissions G17-G18
(tpy)
60
0.01
0.40
4.25
3.65E-04
5.31E-04
1.47E-03
0.18
1,125.62
0.009
0.05
1,121.77
1.46E-03
5.42E-05
1.53E-04
4.78E-04
1.17E-03
1.08E-02
992.02
0.008
0.04
988.62
9.54E-03
1.29E-03
4.78E-05
309.40
1.30E-03
6.67E-04
2.42E-04
1.66E-04
6.79E-05
2.17E-05
0.20
0.44
0.0029
0.062
0.114
0.01
0.11
0.21 0.05
0.03
1.73E-04
5.43E-04
1.33E-03
1.93E-03
5.34E-03
0.01
0.13
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above) for
each engine grouping conservatively assuming the maximum annual operating rate shown for each engine group.
8.58E-05
7.22E-04
2.69E-04
6.57E-04
9.56E-04
2.64E-03
556.91
0.005
0.02
555.01
5.36E-03
2.68E-05 6.78E-06
1.82E-04
1.35E-03
140.71
0.001
0.01
140.23
1.70E-03
4.71E-03
0.00
0.01
0.71
7.65
2.10
14.06 1.92
0.261.57
14.71
# Confidential
Generators G23-G25, FP1, FP2
1 Number of Generator Engines
FP1 (100 kW) Engine 1
FP2 (64 kW) Engine 1
1
G24-G25 (2.5 MW) Engines 2
2 Power Output by Load
10% Load 25% Load 50% Load 75% Load
Full Standby 10% Load 25% Load 50% Load 75% Load
Full Standby
FP1 -- -- -- -- -- -- -- -- -- 100.0
FP2 -- -- -- -- 86.0 -- -- -- -- --
G23 209.0 426.0 772.0 1,124.0 1,483.0 -- -- -- -- --
G24-G25 497.0 1,029.0 1,889.0 2,760.0 3,633.0 -- -- -- -- --
Notes:
1.
10% Load 25% Load 50% Load 75% Load
Full Standby 10% Load 25% Load 50% Load 75% Load
Full Standby
FP1 -- -- -- -- -- -- -- -- -- 0.94
FP2 -- -- -- -- 4.5 -- -- -- -- 0.62
G23 12.6 22.1 38.6 56.7 72.4 1.73 3.03 5.29 7.77 9.92
G24-G25 32.2 57.1 96.5 133.8 175.0 4.41 7.82 13.22 18.33 23.98
Notes:
1.
2.
7,000 Btu/hp-hr
1.3407 hp/kWe
3.
Diesel HHV =0.137 MMBtu/gal
Heat Input
(MMBtu/hr/engine) 2,3
G23 (1.0 MW) Engine
Per the manufacturer specification sheets and performance data for each engine model.
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
G1-G7 diesel fuel consumption was not available from manufacturer specification sheets. Heat Input was calculated using conversion factors from USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, Table 3.4-1, footnote e (October 1996) and Appendix-A:
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines,
Table 3.4-1, footnote a (October 1996):
Engines Group Power Output (bhp/engine) 1 Power Output (kWe/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
# Confidential
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
NOX -- -- -- -- 3.52 -- -- -- -- 3.06
CO -- -- -- -- 1.15 -- -- -- -- 0.60
VOC2 -- -- -- -- 0.21 -- -- -- -- 0.16
Filterable PM3 -- -- -- -- 0.21 -- -- -- -- 0.17
Notes:
1.
2.
3.
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
NOX 6.43 5.34 4.37 4.60 5.97 6.83 3.74 4.02 5.36 6.77
CO 6.03 1.91 0.64 0.21 0.24 5.00 1.99 0.65 0.62 0.88
VOC2 0.73 0.18 0.13 0.09 0.02 0.83 0.40 0.26 0.18 0.11
Filterable PM3 0.40 0.25 0.09 0.03 0.04 0.24 0.22 0.07 0.04 0.04
Notes:
1.
2.
3.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Pollutant
Pollutant
Uncontrolled Emission Factors for FP1 Engine
(g/kW-hr) 1
Uncontrolled Emission Factors for FP2 Engine
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation"
(i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Uncontrolled Emission Factors for G23 Engine
(g/bhp-hr) 1 Uncontrolled Emission Factors for G24-G25 Engines
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation"
(i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
# Confidential
3 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.
4.
4 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
1.93E-04
2.81E-04
7.76E-04
7.70E-03
(lb/MMBtu)3
Benzene
Toluene
Xylenes
0.291.52E-03SO2
Condensable PM
Pollutant
Emission Factor
(>600 hp)
Emission Factor
(≤600 hp)
(lb/MMBtu)1,2
2.85E-04
4.09E-04
9.33E-04
7.70E-03
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
Emission factors are from the U.S. EPA's AP-42, Chapter 3.3, Gasoline and Diesel Industrial Engines, Table 3.3-2 (October 1996). It was conservatively assumed the condensable PM factor for
engines >600 hp is equivalent to engines ≤600 hp.
PAH = Polycyclic Aromatic Hydrocarbons
Pollutant Emission Factor
(lb/MMBtu)1
1,3-Butadiene
Formaldehyde
Acetaldehyde
Acrolein
Total PAH4
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
1.68E-04
9.25E-05
7.67E-04
1.18E-03
3.91E-05
2.12E-04
7.88E-06
2.52E-05
7.89E-05
--
163.05
6.61E-03
1.32E-03
163.61
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
# Confidential
5 Hourly Emission Rates
Pollutant
10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum
Criteria Pollutants
NOX -- -- -- -- 0.78 0.78 -- -- -- -- 0.58 0.58
CO -- -- -- -- 0.25 0.25 -- -- -- -- 0.11 0.11
VOC -- -- -- -- 0.05 0.05 -- -- -- -- 0.03 0.03
PM/PM10/PM2.54 -- -- -- -- 0.05 0.05 -- -- -- -- 0.04 0.04
SO2 -- -- -- -- 0.27 0.27 -- -- -- -- 0.18 0.18
Hazardous Air Pollutants
Benzene -- -- -- -- 8.76E-04 8.76E-04 -- -- -- -- 5.75E-04 5.75E-04
Toluene -- -- -- -- 3.84E-04 3.84E-04 -- -- -- -- 2.52E-04 2.52E-04
Xylenes -- -- -- -- 2.67E-04 2.67E-04 -- -- -- -- 1.76E-04 1.76E-04
1,3-Butadiene -- -- -- -- 3.67E-05 3.67E-05 -- -- -- -- 2.41E-05 2.41E-05
Formaldehyde -- -- -- -- 1.11E-03 1.11E-03 -- -- -- -- 7.28E-04 7.28E-04
Acetaldehyde -- -- -- -- 7.20E-04 7.20E-04 -- -- -- -- 4.73E-04 4.73E-04
Acrolein -- -- -- -- 8.68E-05 8.68E-05 -- -- -- -- 5.70E-05 5.70E-05
Total PAH -- -- -- -- 1.58E-04 1.58E-04 -- -- -- -- 1.04E-04 1.04E-04
Total HAP -- -- -- -- 0.00E+00 3.64E-03 -- -- -- -- 0.00E+00 2.39E-03
Greenhouse Gases
CO2 -- -- -- -- 153.02 153.02 -- -- -- -- 100.54 100.54
CH4 -- -- -- -- 0.01 0.01 -- -- -- -- 0.00 0.00
N2O -- -- -- -- 0.00 0.00 -- -- -- -- 0.001 0.00
CO2e -- -- -- -- 153.55 153.55 -- -- -- -- 100.89 100.89
Notes:
1.
2.
3.
4.
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/gen) = Emission Factor at Load X (g/kWm-hr) x Engine Power at Load X (kWm/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
For engine-specific emission factors: Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
# Confidential
5 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load
Full
Standby Maximum
Criteria Pollutants
NOX 2.96 5.02 7.44 11.40 19.52 19.52 7.48 8.48 16.74 32.61 54.22 54.22
CO 2.78 1.79 1.09 0.52 0.78 2.78 5.48 4.51 2.71 3.77 7.05 7.05
VOC 0.34 0.17 0.22 0.22 0.07 0.34 0.91 0.91 1.08 1.10 0.88 1.10
PM/PM10/PM2.54 0.20 0.26 0.19 0.13 0.21 0.26 0.30 0.56 0.39 0.38 0.51 0.56
SO2 0.003 0.005 0.008 0.012 0.015 0.015 0.007 0.012 0.020 0.028 0.036 0.036
Hazardous Air Pollutants
Benzene 1.34E-03 2.35E-03 4.10E-03 6.03E-03 7.70E-03 7.70E-03 3.42E-03 6.07E-03 1.03E-02 1.42E-02 1.86E-02 1.86E-02
Toluene 4.85E-04 8.51E-04 1.49E-03 2.18E-03 2.79E-03 2.79E-03 1.24E-03 2.20E-03 3.72E-03 5.15E-03 6.74E-03 6.74E-03
Xylenes 3.33E-04 5.84E-04 1.02E-03 1.50E-03 1.91E-03 1.91E-03 8.52E-04 1.51E-03 2.55E-03 3.54E-03 4.63E-03 4.63E-03
Formaldehyde 1.36E-04 2.39E-04 4.17E-04 6.13E-04 7.83E-04 7.83E-04 3.48E-04 6.17E-04 1.04E-03 1.45E-03 1.89E-03 1.89E-03
Acetaldehyde 4.35E-05 7.63E-05 1.33E-04 1.96E-04 2.50E-04 2.50E-04 1.11E-04 1.97E-04 3.33E-04 4.62E-04 6.04E-04 6.04E-04
Acrolein 1.36E-05 2.39E-05 4.17E-05 6.12E-05 7.82E-05 7.82E-05 3.48E-05 6.17E-05 1.04E-04 1.44E-04 1.89E-04 1.89E-04
Total PAH 3.66E-04 6.42E-04 1.12E-03 1.65E-03 2.10E-03 2.10E-03 9.35E-04 1.66E-03 2.80E-03 3.89E-03 5.08E-03 5.08E-03
Total HAP 2.72E-03 4.77E-03 8.33E-03 1.22E-02 1.56E-02 1.56E-02 6.94E-03 1.23E-02 2.08E-02 2.89E-02 3.77E-02 3.77E-02
Greenhouse Gases
CO2 281.53 493.79 862.45 1,266.86 1,617.65 1,617.65 719.45 1,275.80 2,156.13 2,989.53 3,910.07 3,910.07
CH4 0.01 0.02 0.03 0.05 0.07 0.07 0.03 0.05 0.09 0.12 0.16 0.16
N2O 0.002 0.004 0.007 0.010 0.013 0.01 0.006 0.010 0.017 0.024 0.032 0.03
CO2e 282.49 495.48 865.41 1,271.21 1,623.20 1,623.20 721.92 1,280.18 2,163.52 2,999.79 3,923.49 3,923.49
Notes:
1.
2.
3.
Pollutant
G23 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
G24-G25 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
# Confidential
6 Potential to Emit - All Pollutants
Pollutant
Maximum Engine
Operation
(hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.54
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
60
0.0022
0.034
0.066
0.42
3.3
100
Potential Annual Emissions FP1
(tpy)
Potential Annual Emissions FP2
(tpy)
100 60
Potential Annual Emissions G23
(tpy)
Potential Annual Emissions G24-
G25
(tpy)
0.014
0.0027
0.0023
0.013
0.039 0.59
0.0089
0.0018
0.0015
0.0057
0.029
2.8E-04
0
4.0E-04
0.0011
4.7E-04
6.3E-05
2.3E-06
7.5E-06
2.3E-05
0
0.0023
3.1E-04
1.1E-05
3.6E-05
1.1E-04
4.5E-04
0.0077
0.010
0.083
5.5E-05
1.8E-06
1.3E-05
1.9E-05
5.7E-05
8.4E-05
2.3E-04
1.2E-04
5.2E-06
2.9E-06
2.4E-05
3.6E-05
1.2E-06
8.8E-06
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above) for each
engine grouping conservatively assuming the maximum annual operating rate shown for each engine group.
4.1E-05
2.0E-04
5.0
7.7
6.2E-05
3.1E-04
7.7
4.4E-05
235
0.0019
0.010
235
49
3.9E-04
0.0020
49
5.0
1.3E-05
2.9E-05
1.8E-04
7.9E-06
4.3E-06
3.6E-05
# Confidential
Generators G28-29, 32-33
1 Number of Generator Engines
G28-G29 (2.0 MW) Engines 2
G32-G33 (750 kW) Engines 2
2 Power Output by Load
10% Load 25% Load 50% Load 75% Load
Full
Standby
G28-G29 411.0 839.0 1,521.0 2,212.0 2,937.0
G32-G33 153.0 318.0 578.0 843.0 1,114.0
Notes:
1.
10% Load 25% Load 50% Load 75% Load
Full
Standby 10% Load 25% Load 50% Load 75% Load
Full
Standby
G28-G29 26.4 44.8 77.5 107.5 138.0 3.62 6.14 10.62 14.73 18.91
G32-G33 9.6 16.7 28.7 41.4 52.5 1.32 2.29 3.93 5.67 7.19
Notes:
1.
2.
Diesel HHV =0.137 MMBtu/gal
10% Load 25% Load 50% Load 75% Load
Full Standby 10% Load 25% Load 50% Load 75% Load
Full Standby
NOX 7.13 5.03 3.82 4.67 6.56 7.41 5.37 4.31 4.64 6.16
CO 4.36 2.11 0.59 0.39 0.54 3.80 1.68 1.12 0.83 0.48
VOC2 1.08 0.49 0.34 0.23 0.14 0.71 0.28 0.17 0.10 0.05
Filterable PM3 0.49 0.31 0.08 0.04 0.04 0.46 0.33 0.28 0.08 0.04
Notes:
1.
2.
3.
Engines Group Power Output (bhp/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
Heat Input
(MMBtu/hr/engine) 2
Uncontrolled Emission Factors for G32-G33 Engine
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation" (i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Per the manufacturer specification sheets and performance data for each engine model.
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, Table 3.4-1, footnote a
(October 1996):
Pollutant Uncontrolled Emission Factors for G28-G29 Engines (g/bhp-hr) 1
# Confidential
3 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.PAH = Polycyclic Aromatic Hydrocarbons
4 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
Pollutant Emission Factor
(lb/MMBtu)1
Total PAH3
7.76E-04
7.70E-03
1.52E-03SO22
Condensable PM
Benzene
2.12E-04
7.88E-06
2.52E-05
7.89E-05
1.93E-04
2.81E-04Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
Pollutant Emission Factor
(lb/MMBtu)1
163.61
1.32E-03
6.61E-03
163.05
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
# Confidential
5 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load
Full Standby Maximum 10% Load 25% Load 50% Load 75% Load
Full Standby Maximum
Criteria Pollutants
NOX 6.46 9.30 12.81 22.77 42.48 42.48 2.50 3.76 5.49 8.62 15.13 15.13
CO 3.95 3.90 1.98 1.90 3.50 3.95 1.28 1.18 1.43 1.54 1.18 1.54
VOC 0.98 0.91 1.14 1.12 0.91 1.14 0.24 0.20 0.22 0.19 0.12 0.24
PM/PM10/PM2.54 0.47 0.62 0.35 0.31 0.40 0.62 0.17 0.25 0.39 0.19 0.15 0.39
SO2 0.005 0.009 0.016 0.022 0.029 0.029 0.002 0.003 0.006 0.009 0.011 0.011
Hazardous Air Pollutants
Benzene 2.81E-03 4.76E-03 8.24E-03 1.14E-02 1.47E-02 1.47E-02 1.02E-03 1.78E-03 3.05E-03 4.40E-03 5.58E-03 5.58E-03
Toluene 1.02E-03 1.73E-03 2.98E-03 4.14E-03 5.31E-03 5.31E-03 3.70E-04 6.43E-04 1.11E-03 1.59E-03 2.02E-03 2.02E-03
Xylenes 6.98E-04 1.18E-03 2.05E-03 2.84E-03 3.65E-03 3.65E-03 2.54E-04 4.42E-04 7.59E-04 1.09E-03 1.39E-03 1.39E-03
Formaldehyde 2.85E-04 4.84E-04 8.38E-04 1.16E-03 1.49E-03 1.49E-03 1.04E-04 1.81E-04 3.10E-04 4.48E-04 5.68E-04 5.68E-04
Acetaldehyde 9.12E-05 1.55E-04 2.68E-04 3.71E-04 4.77E-04 4.77E-04 3.32E-05 5.77E-05 9.91E-05 1.43E-04 1.81E-04 1.81E-04
Acrolein 2.85E-05 4.84E-05 8.37E-05 1.16E-04 1.49E-04 1.49E-04 1.04E-05 1.80E-05 3.10E-05 4.47E-05 5.67E-05 5.67E-05
Total PAH 7.67E-04 1.30E-03 2.25E-03 3.12E-03 4.01E-03 4.01E-03 2.79E-04 4.85E-04 8.34E-04 1.20E-03 1.53E-03 1.53E-03
Total HAP 5.69E-03 9.66E-03 1.67E-02 2.32E-02 2.98E-02 2.98E-02 2.07E-03 3.60E-03 6.19E-03 8.93E-03 1.13E-02 1.13E-02
Greenhouse Gases
CO2 589.86 1,000.98 1,731.60 2,401.90 3,083.37 3,083.37 214.50 373.13 641.25 925.01 1,173.02 1,173.02
CH4 0.02 0.04 0.07 0.10 0.13 0.13 0.01 0.02 0.03 0.04 0.05 0.05
N2O 0.005 0.008 0.014 0.019 0.025 0.03 0.002 0.003 0.005 0.008 0.010 0.01
CO2e 591.89 1,004.41 1,737.55 2,410.14 3,093.95 3,093.95 215.23 374.41 643.45 928.19 1,177.05 1,177.05
Notes:
1.
2.
3.
For engine-specific emission factors: Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Pollutant
G28-G29 Engines - Hourly Emissions
(lb/hr/engine) 1, 2 G32-G33 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
# Confidential
5 Potential to Emit - All Pollutants
Pollutant
Maximum
Engine Operation
(hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.5
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
6.5E-04
0.023
0.014
0.09
0.9
0.0017
0.037
0.068
2.5
60
Potential Annual Emissions G32-G33
(tpy)
60
Potential Annual Emissions G28-G29
(tpy)
186
0.0015
0.0075
185
0.24
8.3E-05
71
5.7E-04
0.0029
70
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above) for each engine grouping conservatively assuming the maximum annual operating rate shown for each engine group.
1.2E-04
3.3E-04
0.0018
2.4E-04
8.9E-06
2.9E-05
9.0E-05
2.2E-04
3.2E-04
0.0009
6.8E-04
9.2E-05
3.4E-06
1.1E-05
3.4E-05
# Confidential
SLC01 COOLING TOWER PM10 AND PM2.5 EMISSIONS
1) Using Drift Particle Size Analysis, Determine the Percent of Drift
that Results as PM10 and PM2.5 after Evaporation:
Assumptions:
Assume PM10 density = 2.2 g/cm3 = 2.2E-06 ug/um3
Assume H2O density = 1 g/cm3 = 0.000001 ug/um3
Circulating Water TDS = 1330 ppm (Input Value)
(Total Dissolved Solids)
Calculational Method Applied to Determine Particle Size After Evaporation of Water:Interpolate Interpolate
EPRI*to find mass to find mass
Droplet Droplet Droplet Particle Particle Particle EPRI Mass percent of percent of
Diam Vol Mass Mass Vol Diam % Mass Fraction PM10: PM2.5:
(um) (um^3) (ug) (ug) (um^3) (um) Smaller in bin
10 524 0.0005 0.00000 0.32 0.85 0.000 0.0000 0.85
20 4189 0.0042 0.00001 2.53 1.69 0.196 0.1960 1.69
30 14137 0.0141 0.00002 8.55 2.54 0.226 0.0300 2.54 0.22
40 33510 0.0335 0.00004 20.26 3.38 0.514 0.2880 3.38
50 65450 0.0654 0.00009 39.57 4.23 1.816 1.3020 4.23
60 113097 0.1131 0.00015 68.37 5.07 5.702 3.8860 5.07
70 179594 0.1796 0.00024 108.57 5.92 21.348 15.6460 5.92
90 381704 0.3817 0.00051 230.76 7.61 49.812 28.4640 7.61
110 696910 0.6969 0.00093 421.31 9.30 70.509 20.6970 9.30
130 1150347 1.1503 0.00153 695.44 10.99 82.023 11.5140 10.99 75.27
150 1767146 1.7671 0.00235 1068.32 12.68 88.012 5.9890 12.68
180 3053628 3.0536 0.00406 1846.06 15.22 91.032 3.0200 15.22
210 4849048 4.8490 0.00645 2931.47 17.76 92.468 1.4360 17.76
240 7238229 7.2382 0.00963 4375.84 20.29 94.091 1.6230 20.29
270 10305995 10.3060 0.01371 6230.44 22.83 94.689 0.5980 22.83
300 14137167 14.1372 0.01880 8546.56 25.37 96.288 1.5990 25.37
350 22449298 22.4493 0.02986 13571.62 29.59 97.011 0.7230 29.59
400 33510322 33.5103 0.04457 20258.51 33.82 98.340 1.3290 33.82
450 47712938 47.7129 0.06346 28844.64 38.05 99.071 0.7310 38.05
500 65449847 65.4498 0.08705 39567.41 42.28 99.071 0.0000 42.28
600 113097336 113.0973 0.15042 68372.48 50.73 100.000 0.9290 50.73
*EPRI Data - Test Cell, Drift Efficiency = 0.0003%
2)
Circulating Water Rate:20,520 gpm (Input Value)
Drift Rate:0.005 %(Input Value)
Hours per year operation:8760 hr/yr (Input Value)
Total PM = 0.68 lb/hr
(On annual basis =) 2.99 tpy
3) Multiply Total PM by PM10 fraction to obtain PM10 emissions:
0.68 x 0.7527 = 0.514 lb/hr PM10
or, 2.25 tpy
4) Multiply Total PM by PM2.5 fraction to obtain PM2.5 emissions:
0.68 x 0.0022 = 0.002 lb/hr PM10
or, 0.007 tpy
Reference: Joel Reisman et al, 2002. Calculating Realistic PM10 Emissions from Cooling Towers. Environmental Progress,
Volume 21, Issue 2, pages 127–130, July 2002
# Confidential
SLC02 PHASE 1 COOLING TOWER PM10 AND PM2.5 EMISSIONS
1) Using Drift Particle Size Analysis, Determine the Percent of Drift
that Results as PM10 and PM2.5 after Evaporation:
Assumptions:
Assume PM10 density = 2.2 g/cm3 = 0.0000022 ug/um3
Assume H2O density = 1 g/cm3 = 0.000001 ug/um3
Circulating Water TDS = 1330 ppm (Input Value)
(Total Dissolved Solids)
Calculational Method Applied to Determine Particle Size After Evaporation of Water:Interpolate Interpolate
EPRI*to find mass to find mass
Droplet Droplet Droplet Particle Particle Particle EPRI Mass percent of percent of
Diam Vol Mass Mass Vol Diam % Mass Fraction PM10: PM2.5:
(um) (um^3) (ug) (ug) (um^3) (um) Smaller in bin
10 524 0.0005 0.00000 0.32 0.85 0.000 0.0000 0.85
20 4189 0.0042 0.00001 2.53 1.69 0.196 0.1960 1.69
30 14137 0.0141 0.00002 8.55 2.54 0.226 0.0300 2.54 0.22
40 33510 0.0335 0.00004 20.26 3.38 0.514 0.2880 3.38
50 65450 0.0654 0.00009 39.57 4.23 1.816 1.3020 4.23
60 113097 0.1131 0.00015 68.37 5.07 5.702 3.8860 5.07
70 179594 0.1796 0.00024 108.57 5.92 21.348 15.6460 5.92
90 381704 0.3817 0.00051 230.76 7.61 49.812 28.4640 7.61
110 696910 0.6969 0.00093 421.31 9.30 70.509 20.6970 9.30
130 1150347 1.1503 0.00153 695.44 10.99 82.023 11.5140 10.99 75.27
150 1767146 1.7671 0.00235 1068.32 12.68 88.012 5.9890 12.68
180 3053628 3.0536 0.00406 1846.06 15.22 91.032 3.0200 15.22
210 4849048 4.8490 0.00645 2931.47 17.76 92.468 1.4360 17.76
240 7238229 7.2382 0.00963 4375.84 20.29 94.091 1.6230 20.29
270 10305995 10.3060 0.01371 6230.44 22.83 94.689 0.5980 22.83
300 14137167 14.1372 0.01880 8546.56 25.37 96.288 1.5990 25.37
350 22449298 22.4493 0.02986 13571.62 29.59 97.011 0.7230 29.59
400 33510322 33.5103 0.04457 20258.51 33.82 98.340 1.3290 33.82
450 47712938 47.7129 0.06346 28844.64 38.05 99.071 0.7310 38.05
500 65449847 65.4498 0.08705 39567.41 42.28 99.071 0.0000 42.28
600 113097336 113.0973 0.15042 68372.48 50.73 100.000 0.9290 50.73
*EPRI Data - Test Cell, Drift Efficiency = 0.0003%
2)
Circulating Water Rate:3,600 gpm (Input Value)
Drift Rate:0.0005 %(Input Value)
Hours per year operation:8760 hr/yr (Input Value)
Total PM = 0.012 lb/hr
(On annual basis =) 0.052 tpy
3) Multiply Total PM by PM10 fraction to obtain PM10 emissions:
0.012 x 0.7527 = 0.009 lb/hr PM10
or, 0.04 tpy
4) Multiply Total PM by PM2.5 fraction to obtain PM2.5 emissions:
0.012 x 0.0022 = 0.000027 lb/hr PM2.5
or, 0.00012 tpy
Reference: Joel Reisman et al, 2002. Calculating Realistic PM10 Emissions from Cooling Towers. Environmental Progress, Volume 21, Issue 2, pages
127–130, July 2002
# Confidential
1/1
November 21, 2024
Ramboll Americas Engineering
Solutions
200 S 257 E, Suite 550,
Salt Lake City, UT 84111
USA
T [phone]
www.ramboll.com
Confidential
Via Electronic Mail
John Jenks
Environmental Engineer
Utah Department of Environmental Quality
Division of Air Quality
[e-mail]
CC: Dave Prey, UDAQ
Response to Serious Ozone Nonattainment Area Designation – Potential
Impact to eBay Inc. – Salt Lake City Data Center
Dear Mr. Jenks,
Enclosed please find eBay’s updated Notice of Intent (NOI) application to request
authority to update Approval Order (AO) DAQE-AN141800011-21, to account for
changes in equipment locations and emission rates. As outlined in the attached NOI
supplement, eBay intends to maintain minor source status by keeping the facility’s
Potential to Emit (PTE) of NOx below 50 tons per year. This NOI is intended to
supplement the previously submitted NOI dated July 18, 2023.
Thank you for considering our notice of intent. Please feel free to contact Megan
Neiderhiser if you have any comments or questions about this application:
Megan Neiderhiser, PE
Principal
Ramboll Americas Engineering Solutions
Salt Lake City, UT 84111
Phone: [phone]
[e-mail]
Sincerely,
Megan Neiderhiser, PE Principal
CC: Rei Zhang, Ramboll Dave Prey, UDAQ
Declan O’Riordan, eBay
Adam Englebright, eBay

Confidential

Intended for Utah Division of Air Quality
Prepared for eBay
South Jordan, Utah
Prepared by Ramboll Americas Engineering Solutions Inc.
Salt Lake City, UT
Project Number
1940109969
Date November 2024

NOTICE OF INTENT APPLICATION
EBAY SLC DATA CENTER
SOUTH JORDAN, UTAH

Notice of Intent Application eBay SLC Data Center
Contents i Ramboll
Confidential
CONTENTS

1. INTRODUCTION 1
2. FACILITY DESCRIPTION 2
3. EMISSIONS CALCULATIONS 3
3.1 Diesel-Fired Emergency Standby Generators 3
3.2 Diesel Storage Tanks 4
3.3 Cooling Towers 4
3.4 Potential Emissions 4
Notice of Intent Application eBay SLC Data Center
Contents i Ramboll
Confidential
TABLES
Table 1. Generator IDs 2
Table 2. Facility-Wide Potential Emissions 5
Table 3. Potential to Emit: Criteria Pollutants & GHG 6
APPENDICES
Appendix 1
Figures
Appendix 2
UDAQ Approval Order Modification Forms
Appendix 3
Generator Manufacturer Specifications and Emissions Data Sheets (Submitted electronically)
Appendix 4
Potential Emissions Calculations

Notice of Intent Application eBay SLC Data Center
Facility Description 1 Ramboll
Confidential
1. INTRODUCTION
eBay Inc. (“eBay” or “the applicant”) is submitting this Notice of Intent (NOI) Application to
the Utah Department of Environmental Quality – Division of Air Quality (UDAQ) to request
authority to update DAQE-AN141800011-21. With this Approval Order (AO) modification,
eBay proposes to update the operational hours of two diesel-fired emergency generators
from 66 hours a year to 100 hours a year, and reduce the operational hours for twenty-nine
(29) diesel-fired emergency generators from 66 hours a year to 60 hours a year. The
applicant is also requesting to relocate two diesel-fired emergency backup generators,
remove two diesel-fired emergency generators from the permit, and remove the Bloom
Energy Servers at eBay’s SLC Data Center (facility) located in South Jordan, Salt Lake
County, Utah.
The Northern Wasatch Front Nonattainment Area is anticipated to be reclassified from
moderate to serious ozone nonattainment status in February 2025.1 This reclassification
reduces the Title V Major Source threshold from 70 tons per year (tpy)2 to 50 tpy for ozone
precursors including both NOx and VOC. eBay is currently permitted as a synthetic minor
source with the potential to emit (PTE) of 57 tons of NOx per year. Because eBay's PTE
exceed the proposed major source threshold of 50 tpy, UDAQ requires that eBay either
complete a RACT analysis for the emissions units at the facility, or submit a Notice of Intent
(NOI) application to lower the PTE below 50 tpy of NOx and VOCs to remain a minor source.
eBay elects to submit an NOI to reduce PTE below 50 tpy of NOx and VOC.
As a result of the changes described in this NOI application, eBay’s NOx emissions would
decrease from 57 tpy of NOx to 45.55 tpy of NOx, which is below the lower 50 tpy threshold.
eBays VOC emissions will continue to remain below the 50 tpy VOC threshold.
The facility currently includes 31 diesel-fired emergency backup generators that provide
electricity to the facility in the event of an emergency, two fire pump engines, and two
cooling towers. Site location maps are provided in Appendix 1.
The facility is currently classified as a synthetic minor source of air emissions with respect to
the Title V and New Source Review (NSR) permitting programs. Since the project decreases
the potential to emit of all air pollutants, a full Notice of Intent (NOI) application is not
required, but eBay is required to notify UDAQ of the modifications in accordance with the
requirements of the Utah Administrative Code (UAC) Rule 307-401-12.3 Approval for the
proposed actions to reduce NOx emissions below the 50 tpy threshold could be achieved
mirroring the process of a R307-401-12 administrative amendment.4 The applicant is hereby
requesting an Approval Order (AO) modification from UDAQ to cover increased operating
hours of two generators, decreased operating hours of twenty-nine (29) generators,
relocation of three generators, as well as the removal of two existing generators and the
Bloom Energy Servers at the facility.

1 Letter from UDAQ to eBay dated May 31, 2023, and Northern Wasatch Front Serious Ozone SIP Stakeholder
Meeting, held Jun 13, 2023.
2 Currently applicable for PM2.5 precursors. 3 Utah Administrative Code. R307-401-12. Permit: New and Modified Sources. Approval Order. Available at: https://adminrules.utah.gov/public/rule/R307-401/Current%20Rules?
4 Email from John Jenks (UDAQ) to Megan Neiderhiser on June 27, 2023
Notice of Intent Application eBay SLC Data Center
Facility Description 2 Ramboll
Confidential
2. FACILITY DESCRIPTION
The applicant is proposing to do the following changes to the data center located in Salt Lake
County, Utah.
1) increasing hours of operation for G15 and G16 from 66 operational hours per year to 100
operational hours per year,
2) decreasing hours of operation for G01-G14, G17-G29, and G32-33 from 66 operational
hours per year to 60 operational hours per year,
3) relocation of generators G26 and G27 to G30 and G31 locations,
4) removal of G30 and G31 from the permit,
5) removing the Bloom Energy Servers.
A list of the post change generator identification (ID) numbers is provided in Table 1. A
facility map of generator locations is provided in Appendix 1, and the manufacturer’s
specification sheets for the generators are provided in Appendix 3.5
Table 1. Generator IDs
Emission Point ID Numbers for Generators Generator Manufacturer and Engine Size (per engine)
G1-G7 Detroit Diesel - 3.25 Megawatts
(MW)
G8-G14 Caterpillar - 3.0-3.1 MW
G15-G16; G19-G22; G26-
G27 Caterpillar - 2.0 MW
G17-G18 Caterpillar - 1.5 MW
G23 Caterpillar - 1.0 MW
G24-G25 Caterpillar - 2.5 MW
FP1 Caterpillar - 100 kilowatts (kW)
FP2 John Deere - 64 kW
G28-G29 Caterpillar - 2.0 MW
G32-G33 Caterpillar - 750 kW

Other sources of emissions at the facility include diesel storage tanks for each generator, and
two cooling towers. The cooling towers would not be changed as part of this modification,
and emissions from diesel storage tanks are negligible.

5 Emission specification sheets are included for all existing and proposed generators at the facility since emissions
of existing engines were revised to conservatively utilize not-to-exceed factors instead of nominal emissions factors, which were previously used in potential emissions calculations.
Notice of Intent Application eBay SLC Data Center
Emissions Calculations 3 Ramboll
Confidential
3. EMISSIONS CALCULATIONS
Pollutants emitted from the facility include NOX; CO; VOCs; sulfur dioxide (SO2); particulate
matter (PM); PM less than 10 microns in diameter (PM10); PM less than 2.5 microns in
diameter (PM2.5); hazardous air pollutants (HAPs); and greenhouse gases, represented in
terms of carbon dioxide equivalents (CO2e).
The methodology used to estimate the potential emissions from each source is discussed in
the following sections. The manufacturer’s specification sheets for the generators are
provided in Appendix 3, and detailed calculations are provided for all emissions sources in
Appendix 4.
3.1 Diesel-Fired Emergency Standby Generators
Operation of the diesel-fired emergency generator engines would result in emissions of
byproducts of combustion. The derivation of potential hourly and annual emissions is
presented below.
3.1.1 Derivation of Potential Hourly Emissions
The following emission factors were used to estimate the potential hourly emissions from the
emergency generators:
• Except as noted below, the manufacturer’s not-to-exceed, engine-specific emission factors
for NOX, VOC (hydrocarbons), CO, and filterable PM were used to estimate the emissions
of those pollutants at each generator load. On-site operational measurements (testing
data) of the generators was used for the engine power output where available; this site-
specific test data accounts for the increased altitude of the site compared to the
manufacturer’s baseload output. The unadjusted engine-specific emission factors at the
corresponding percentage load were applied to the altitude-adjusted (lowered) engine
power output to estimate potential emissions.6 It was conservatively assumed that all
particulate matter in the engine exhaust is PM2.5. Potential hourly emissions were based
on the maximum hourly emission rate for each pollutant at any engine load for each
engine group.
– Note, for engines G1-G7, the manufacturer provided emissions on a mechanical
kilowatt (kWm) basis. Therefore, the engine rating used for emissions calculations is
3,490 kWm. However, the engine rating in the current AO is in electrical megawatt
(MWe). Thus, Table 1 lists the engine rating in MWe (i.e. 3.25 MW), which is
consistent with all other engines which are listed in electrical wattages.
• For all engines except the fire pumps, emissions of SO2, condensable PM, and HAP were
estimated based on the diesel fuel emission factors in the USEPA’s AP-42, Chapter 3.4,
Large Stationary Diesel and All Stationary Dual-fuel Engines (October 1996). The
emission factor for SO2 was calculated based on the maximum allowable diesel fuel sulfur
content of 0.0015% by weight, per 40 CFR 60 Subpart IIII. The emissions calculations
assumed a diesel high heating value of 0.137 MMBtu/gal, based on AP-42, Table 3.4-1,
footnote a.

6 G8-G14 are all the same generator model and size (3,000 kW standby, C175-16), but can be further grouped into two different serial
numbers (G8, and G9-G14). A spec sheet containing a site-tested load was not available for G8, but was available for G9-G14. Therefore, the
site-tested load from G9-G14 was applied to the entire group.
Notice of Intent Application eBay SLC Data Center

Confidential
• For fire pump engines, emissions of SO2 and HAP were estimated based on the diesel fuel
emission factors in the USEPA’s AP-42, Chapter 3.3, Gasoline and Diesel Industrial
Engines, Table 3.3-2 (October 1996). It was conservatively assumed that the fire pumps
have the same condensable PM emissions factor as Large Stationary Diesel and All
Stationary Dual-fuel Engines.
• Emissions of CO2e from diesel fuel combustion were estimated based on the GHG emission
factors and global warming potentials provided in 40 CFR 98.
3.1.2 Derivation of Potential Annual Emissions
Potential annual emissions from the facility were estimated assuming 60 hours per year per
engine for all existing and proposed generators (except for generators G15 and G16), and
100 hours per year for the two fire pump engines and G15 and G16. The operational limit of
100 hours per year for generators is requested to meet the 100 hours per year maximum
allowable non-emergency run time per 40 CFR 60 Subpart IIII.7
3.2 Diesel Storage Tanks
Emissions of VOC from the diesel tanks would result from the standing and working losses.
Consistent with previous permitting applications, these emissions are considered negligible
and are not included as part of this application.
3.3 Cooling Towers
Emissions of PM from the two cooling towers are the result of the cooling water coming into
direct contact with the air through the tower and causing water droplets to carry PM from the
cooling towers. The emissions are based on the cooling tower recirculation rate, total
dissolved solids content in the cooling water, the drift loss from the tower, and the particle
size after evaporation of the water. These emissions were estimated by using the method
from Calculating Realistic PM10 Emissions from Cooling Towers.8 Potential annual emissions
were based on 8,760 hours per year of operation. Cooling tower emissions have not
changed as a result of this application.
3.4 Potential Emissions
A summary of the potential emissions for the facility are provided in Table 2 and indicate
that the facility would be a minor source of air emissions.9 As the project does not increase
the potential to emit of any air pollutant or cause emissions of any new air pollutant, the
applicant is exempt from the requirement to conduct air dispersion modeling.

7 As confirmed via phone conversation with UDAQ, the agency does not regulate run time or emissions resulting from emergency operations of the generators. Additionally, the agency does not regulate run time or emissions
during the initial shakedown period of new engines prior to the engines becoming operational, not to exceed 180
days, in accordance with the definition of “Net Emissions Increase” in UAC Rule 307-101-2. Available at: https://adminrules.utah.gov/public/rule/R307-101/Current%20Rules?
8 Joel Reisman and Gordon Frisbie. Calculating Realistic PM10 Emissions from Cooling Towers. Available at:
https://www.nrc.gov/docs/ML1232/ML12325A097.pdf 9 In previous NOI submittals, nominal emissions data was used to calculate potential emissions. As part of this
application, emissions from existing emergency generators use not-to-exceed manufacturer emissions data for a more conservative approach, following the methodology used in DAQE-AN141800011-21.
Notice of Intent Application eBay SLC Data Center
Emissions Calculations 5 Ramboll
Confidential
Table 2. Facility-Wide Potential Emissions
Pollutant
Potential Annual Emissions (tpy) Facility-Wide Potential Annual Emissions (tpy)
Title V Major Source Threshold1,2,3 (tpy)
Above Threshold? Emergency
Generators & Fire
Pumps
Cooling Towers
NOX 45.55 -- 45.55 70 No
CO 5.89 -- 6.68 100 No
VOC 1.15 -- 1.44 50 No
PM 0.63 3.04 3.70 100 No
PM10 0.63 2.29 2.94 100 No
PM2.5 0.63 6.84E-03 0.66 70 No
SO2 0.056 -- 0.056 70 No
Maximum
Individual
HAP
(Benzene)
0.0048 --
0.0048
10 No
Total HAP 0.036 -- 0.035 25 No
CO2e 3677.7 -- 3669.63 N/A N/A

Notes:
1) UAC R307-420 applies when Salt Lake County is designated as a maintenance area with respect to the 2015 8-hr Ozone National Ambient Air Quality
Standard (NAAQS). Salt Lake County is currently classified as Moderate nonattainment for the Ozone standard. However, UAC does not have
regulations codified for when Salt Lake County is designated as nonattainment, and therefore, the Major Source classification for VOC from UAC R307-
420 was used. UAC R307-420 available at: https://rules.utah.gov/publicat/bulletin/2017/20170601/41641.htm.
2) Utah Administrative Code. R307-403. Permit: New and Modified Sources in Nonattainment Areas and Maintenance Areas.
https://rules.utah.gov/publicat/code/r307/r307-403.htm#E2.
3) The Major Source threshold is anticipated to be reduced from 70 tons per year (tpy) to 50 tpy for ozone precursors, including both NOx and VOC, in
February 2025.

Notice of Intent Application eBay SLC Data Center

Confidential
Table 3. Potential to Emit: Criteria Pollutants & GHG
Criteria Pollutants Current Permitted Emissions (tons / year) Proposed Emissions Changes (tons/year) Proposed Emissions (tons/year)
PM10 (Total) 3.00 -0.057 2.94
PM10 (Fugitive) -- -- --
PM2.5 0.71 -0.058 0.65
NOX 56.35 -10.80 45.55
SO2 0.060 -3.59E-03 0.056
CO 11.38 -4.70 6.68
VOC 2.26 -0.82 1.44
VOC (Fugitive) -- -- --
NH3 -- -- --
Greenhouse Gases Mass Basis CO2e Mass Basis CO2e Mass Basis CO2e
CO2 -- -- -- -- 3,657.08 3,657.08
CH4 -- -- -- -- 0.15 3.71
N2O -- -- -- -- 0.03 8.84
HFCs -- -- -- -- -- --
PFCs -- -- -- -- -- --
SF6 -- -- -- -- -- --
Total CO2e 41,355.00 41,355.00 -37,685.37 -37,685.37 3,669.63 3,669.63
Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential
APPENDIX 1
FIGURES
!
!
!
!
!
!
!!
!
!
!
^_
Orem
Sandy
Provo
Ogden
Layton
Millcreek
West JordanTaylorsville
South Jordan
Salt Lake City
50 West Broadway, Suite 300Salt Lake City, UT 84101
0 20
Kilometers
FIGUREA1Facility Location andSurrounding AreaseBay SLC Data CenterSouth Jordan, Utah
Arizona
Ne
v
a
d
a
Idaho
Wyoming
Co
l
o
r
a
d
o
£¤89
§¨¦15
^_FacilityStreets
U.S Interstates
Highways
State
County
WASATCHCOUNTY
TOOELECOUNTY
SUMMITCOUNTY
BOX ELDERCOUNTY
DAVISCOUNTY
WEBERCOUNTY
MORGANCOUNTY
UTAHCOUNTY
SALTLAKECOUNTY§¨¦80
§¨¦84
eBayDataCenter
eBay
SLC DataCenter
Notice of Intent Application eBay SLC Data Center
Ramboll
APPENDIX 2
UDAQ APPROVAL ORDER MODIFICATION 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
2
3
4
5
6
7
8
9
NOI Application Information [R307-401]
1
2
3
4 N/A
5
6
A
7
A
B
C
8
A
9
A N/A
B N/A
10
A N/A
B N/A
Signature on Application
Detailed description of the project and source process.
11/7/2024
eBay Inc.
Company name, mailing address, physical address, and telephone number.
Company contact (name, mailing address, telephone number).
Name and contact of person submitting NOI application (if different than 2).
Source Universal Transverse Mercator (UTM) coordinates.
Source Standard Industrial Classification (SIC) Code.
Area designation (attainment, maintenance, or nonattainment).
Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.)
Source size determination (Major, Minor, PSD).
Current Approval Order(s) and/or Title V Permit Numbers.
Composition and physical characteristics of effluent
(Emission rates, temperature, volume, pollutant types, and concentration).
Discussion of fuels, raw materials, and products consumed/produced.
Description of equipment used in the process and operating schedule.
Description of changes in the process, production rates, etc.
Site plan of source with building dimensions, stack parameters, etc.
Best Available Control Technology (BACT) Analysis [R307-401-8]
BACT analysis for all new and modified equipment.
Emissions Related Information [R307-401-2(b)]
Emission calculations for each new/modified units and site-wide
(Include PM10, PM2.5, NOX, SO2, CO, VOCs, HAPs, and GHG).
References/assumptions, SDS, for each calculation and pollutant.
All speciated HAP emissions (list in lbs/hr).
Emissions Impact Analysis - Approved Modeling Protocol [R307-410]
Note: The Division for Air Quality will not accept documents containing confidential information
or data. Documents containing confidential information will be returned to the Source submitting
the application.
Nonattainment/Maintenance Areas - Major NSR/Minor (Offsetting Only) [R307-403]
NAAQS Demonstration, Lowest Achievable Emission Rate, Offset
Requirements.
Alternate site analysis, Major source ownership compliance certification.
Major Sources in Attainment or Unclassified Area (PSD) [R307-405, R307-406]
Air quality analysis (air model, met data, background data, source impact
analysis).
Visibility impact analysis, Class I area impact.
# Confidential
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
1. Company name and mailing address:2. Company** contact for environmental matters:
Company Name:Contact:
Title:
Phone No.:
Phone No.:Email:
Fax No.:
3. Source name and physical address (if different from above):
Company Name:SLC Data Center
Mailing Address:6614 West Crimson View Drive UTM E:meters
South Jordan, UT 84095 UTM N:meters
Phone No.:System & Datum:
Fax No.:
5. The Source is located in:County.6. Standard Industrial Classification Code
7. If request for modification, AO# to be modified:
DAQE #:
Dated:
8. Brief (50 words or less) description of process:
Electronic NOI
Hard Copy Submittal:Electronic Copy Submittal:Both:
Title:
Telephone No:
Email:Date:
411299.0
11/7/2024
General Owner and Source Information
eBay Inc.Charlie Hill
Mailing Address:2145 Hamilton Ave Regional Facilities Operations
Manager
San Jose, CA 95125
[phone] [e-mail]
[phone] **Company contact only; consultant or independent contractor
contact information can be provided in a cover letter.
4. Source Property Universal Transverse Mercator
Coordinates (UTM), including System and Datum:
Signature:Regional Facilities Operations
Manager
4490858.0
NAD83, Zone 12 N
Salt Lake 7374
DAQE-AN141800011-21
7-Jan-21
Please see Section 2 of the enclosed NOI application report.
9. A completed and accurate electronic NOI submitted to DAQ Permitting Managers Jon Black ([e-mail]) or Alan
Humpherys ([e-mail]) can expedite review process. Please mark application type.
General Owner and Source Information
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.
0
Charlie Hill [e-mail]
Name (Type or Print)
# Confidential
Form 4 Company:
Emissions Information Site:
Criteria / GHGs
Utah Division of Air Quality
New Source Review Section
If submitting a new permit, then use Form 3
3. Permit Change Type:New Increase*
Yes No
Requested Changes
eBay Inc.
SLC Data Center
Process Data - For Modification/Amendment ONLY
1. Permit Number DAQE-AN141800011-21
Hours limits for generators G1-G29, and G32-G33; See below
2. Name of process to be modified/added:
Emergency generator Equipment
Process
End product of this process:
Removal of two emergency generators from the overall
operation of facility; relocation of two generators; Non-
Emergency runtime hour limits modified for existing permitted
generators; removal of servers
Condition Change:1) relocation of generators G26 and G27 to
G30 and G31 locations, with the
subsequent removal of G30 and G31;
2) increasing hours of operation for G15
and G16 from 66 operational hours per
year to 100 hours per year;
3) Decreasing hours of operation from 66
operational hours per year to 60
operational hours per year for G01-G14,
G17-G29, and G32-G33; and
4) removal of the Bloom Energy Servers
Other:
4. Does new emission unit affect existing permitted process
limits?
5. Condition(s) Changing:
Emitting Unit(s)Capacity(s)Manufacture Date(s)
6. Description of Permit/Process Change** See details in application report
7. New or modified materials and quantities used in process. **
Material Quantity Annually
G15-G16 hours of operation 100 hrs/yr/generator for Non-Emergency Operations
G01-G14, G17-G29, and G32-G33 hours of operation 60 hrs/yr/generator for Non-Emergency Operations
8. New or modified process emitting units **
*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.
# Confidential
Form 5 Company:
Emissions Information Source:
Criteria / GHGs
Utah Division of Air Quality
New Source Review Section
CO2e CO2e CO2e
----3,657.08
----3.71
----8.84
------
------
------
41,355.00 -37,685.37 3,669.63
*Potential to Emit to include pollution control equipment as defined by R307-401-2.
Form 5 Company:
Emissions Information Source:
HAP's
Utah Division of Air Quality
New Source Review Section
**Defined in Section 112(b) of the Clean Air Act.
***Use additional sheets for pollutants if needed.
PM10 (Total)3.00 -0.057 2.94
PM10 (Fugitive)------
eBay Inc.
Facility-Wide
Potential to Emit* - Criteria Pollutants & GHGs
Criteria Pollutants Permitted Emissions
(tons / year)
Emissions Increases
(tons/year)
Proposed Emissions
(tons/year)
SO2 0.060 -3.59E-03 0.056
CO 11.38 -4.70 6.68
PM2.5 0.71 -0.058 0.65
NOX 56.350 -10.80 45.55
NH3 ------
VOC 2.26 -0.82 1.44
VOC (Fugitive)------
CH4 ----0.15
N2O ----0.03
Greenhouse Gases Mass Basis Mass Basis Mass Basis
CO2 ----3,657.08
SF6 ------
Total CO 2 e 41,355.00 -37,685.37 3,669.63
HFCs ------
PFCs ------
eBay Inc.
Facility-Wide
Hazardous Air Pollutants**
Hazardous Air Pollutants***
Permitted
Emissions
(tons/year)
Emissions
Increases
(tons/year)
Proposed
Emissions
(tons/year)
Emissions Increase
(pounds/hour)
Benzene ----0.017 --
Toluene ----6.31E-03 --
Xylenes ----4.34E-03 --
1,3-Butadiene ----3.04E-06 --
Formaldehyde ----1.86E-03 --
Acetaldehyde ----6.23E-04 --
Acrolein ----1.83E-04 --
Total HAP 0.12 -0.085 0.035 --
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate --gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G1-G7
11/7/2024
Equipment Information
Average Maximum
Detroit Diesel N/A N/A
20V4000G83L N/A N/A
N/A N/A
60 hrs/yr/generator for non-emergency operations.--
4,678 3,490
< 0.0015 Neg.
4,577 3,415
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
15,642 --
137,030
237
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G1-G7
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G1-G7 Detroit Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations
are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G1-G7
11/7/2024
(b)Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 122 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G8-G14
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
C175-16 N/A N/A
N/A N/A
0--
4,376 3,000
< 0.0015 Neg.
3,969 2,692
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
13,906 --
137,030
211
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G8-G14
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G8-G14 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G15-G16
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
3516C N/A N/A
N/A N/A
100 hrs/yr/generator for non-emergency operations.
--
2,937 2,000
< 0.0015 Neg.
2,563 1,745
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
13,800 --
137,030
138
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G15-G16
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G15-G16; G19-G22;
G26-G27 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 60 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G17-G18
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
3512C N/A N/A
N/A N/A
0--
2,206 1,500
< 0.0015 Neg.
1,838 1,250
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
6,904 --
137,030
105
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G17-G18
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G17-G18 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
138
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
< 0.0015 Neg.
2,563 1,745
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
8,280 --
137,030
N/A N/A
60 hrs/yr/generator for non-emergency operations.
--
2,937 2,000
Caterpillar N/A N/A
3516C N/A N/A
eBay Inc.
G19-G22, G26-G27
11/7/2024
Equipment Information
Average Maximum
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G19-G22, G26-G27
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Approx. 5,100
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
G15-G16; G19-G22;
G26-G27 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 40 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G23
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
C32 N/A N/A
N/A N/A
0--
1,483 1,000
< 0.0015 Neg.
1,290 875
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
4,778 --
137,030
72
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G23
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G23 CAT Diesel
Generator
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 99 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G24-G25
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
3516C N/A N/A
N/A N/A
0--
3,633 2,500
< 0.0015 Neg.
3,052 2,100
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
11,550 --
137,030
175
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G24-G25
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G24-G25 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 79 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G28-G29
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
3516C N/A N/A
N/A N/A
02020+
2,937 2,000
< 0.0015 Neg.
2,563 1,745
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
9,108 --
137,030
138
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G28-G29
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G28-G29 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 30 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
G32-G33
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
C27 N/A N/A
N/A N/A
02020+
1,114 750
< 0.0015 Neg.
1,114 750
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
3,465 --
137,030
53
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
G32-G33
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
G32-G33 CAT Diesel
Generators
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
* Engineering Estimate Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 14.6*gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
FP1
11/7/2024
Equipment Information
Average Maximum
Caterpillar N/A N/A
D4B01369 N/A N/A
N/A N/A
100 hrs/yr/generator for non-emergency operations.--
--100
< 0.0015 Neg.
--100
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
610*--
137,030
6.1*
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
FP1
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
FP1 CAT Fire Pump
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
1. Manufacturer / Model:2. Operating Time of Emissions Source
Manufacturer:hr/day hr/day
Model No.:day/wk day/wk
wk/yr wk/yr
Date Engine Was Constructed / Reconstructed:
3. Manufacturer's Rated Output at Baseload (ISO):bhp kW
Proposed Site Operated Range:bhp kW
4. Are you operating site equipment on pipeline quality natural gas?Yes No N/A
5. Are you on an interruptible gas supply?6. Annual Consumption of Fuel:
Yes No
If Yes, Alternate Fuel?MMscf/yr
7. Maximum Firing Rate:8. Average Firing Rate:
Btu/hr Btu/hr
9. Type of Oil:
No. 1 No. 2 No. 4 No. 5 No. 6 Other?
10. Annual Fuel Consumption:11. Heat Content:
gallons/year/engine Btu/lb OR
Btu/gal
12. Sulfur Content.wt.%13. Ash Content wt.%
14. Average Firing Rate 4.5 gal/hr/engine 15. Maximum Firing Rate gal/hr/engine
16. Direction of Firing:
Horizontal Tangential Other (Specify)
17. Application of Internal Combustion Engine:18. Cycle
Electric Generation (Base Load)Simple Cycle
Electric Generation (Peaking)Regenerative Cycle
Emergency Generator Cogeneration
Driving Pump / Compressor Combined Cycle
Exhaust Heat Recovery N/A
Other (Specify)
19. Manufacturer's Emissions Data (Provided in Grams per Brake-Horsepower-Hour):
NOX VOC
CO Formaldehyde
*Please refer to Appendix 4 of the enclosed NOI application for detailed engine-specific emissions information.
Method of Emissions Control:
Lean Premix Combustors Oxidation Catalyst Water Injection Other?
Other Low-NOX Combustor SCR Catalyst Steam Injection
eBay Inc.
FP2
11/7/2024
Equipment Information
Average Maximum
John Deere N/A N/A
JU4H-UFADJ8 N/A N/A
N/A N/A
100 hrs/yr/generator for non-emergency operations.--
86.00 64.00
< 0.0015 Neg.
86.00 64.00
Gas-Firing
N/A N/A
N/A N/A
Oil-Firing
ULSD
450 --
137,030
4.5
Operation
Emissions Data
--*--*
--*No Data
20. Attach manufacturer's information showing emissions of NOX, CO, VOC, SO2, CH2O, PM10, PM2.5, 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.
# Confidential
Form 11 Company:
Internal Combustion Engines Source:
Date:
Utah Division of Air Quality
New Source Review Section
eBay Inc.
FP2
11/7/2024

21. On separate sheets provide the following:
A
B
C
D
E
Number Name
Conc.
(Vol.%)
(3)
LB/HR
(4)
TPY
(5)Zone East
(m)
North
(m)
Diameter
(ft.)
Velocity
(ft/sec)
Temp.
(deg. F)
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL:feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 680 F AND 14.7 PSIA
General Instructions for this form:
1
2
3
4
5
6
7
(a)
(b)
All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3.
Additional Information
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.
Exhaust parameter information on attached form.
All calculations used for the annual emission estimates must be submitted with this form to be deemed complete.
If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Internal Combustion Engine
Form 11 (Continued)
Emissions Sources
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
Emission Point
(1)
Chemical Composition of Total
Stream
Air Contaminant
Emission Rate
UTM Coordinates of
Emission Point
(6)
Stack Sources
(7)
Height
Above
Ground
(ft.)
Height
Above
Structure
(ft.)
Exit Data
Component /
Air Contaminant
Name
(2)
FP2 John Deere Fire
Pump
NO X
Refer to Appendix 4
to this NOI
application for
detailed engine-
specific emissions
information.
See NOI Report and associated Table B1.
CO
VOC
PM
Acetaldehyde
PM 10
PM 2.5
SO 2
CO 2
CH 4
N 2 O
CO 2 e
Benzene
Toluene
Xylenes
Formaldehyde
Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
Acrolein
Total PAH
Total HAP
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.
Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc.
Abbreviations are OK.
Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
Approx. 5,100
Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
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.
Supply additional information as follows if appropriate:
Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal
discharge with a note.
Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
# Confidential
Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential Confidential
APPENDIX 3
GENERATOR MANUFACTURER SPECIFICATIONS AND EMISSIONS DATA
SHEETS (SUBMITTED ELECTRONICALLY)
Generator NOI ID
Emission
Factor
Page
Number
Source Document Title
Generator
Site Rating
Page
Number
Source Document Title Notes
Detroit Diesel - 3250 kilowatts (kW)G1 - G7 2
EDS40000527 (20V4000G83L - 3490kWm - 3000kWe - 3D Standby Application).pdf 80-86 G01-G07_ 128014-003 Atlantic Detroit Diesel Allison Closeout Submittal Rev 0 11-30-10 Emission factors provided by manufacturer. Site Load test from Generator Submittal.
Caterpillar - 3100 kW G08
33 - 34, 36-
37
G08 QS Mech Gen - 26-3225-01 Diesel Engine Driven
Generator - Resubmittal - For Approval.pdf N/A N/A Same model number (C175-16) as G09-G14.
Caterpillar - 3100 kW G09 - G14 34 G09-G14 26-3213-01 - 00005 - 2 - Diesel Engine Driven Generators Submittal Rev. 1 - FWT Updates
(mjs) AHA Response - 2015-02-09.pdf
8, 54 G09-G14 26-3213-01 - 00005 - 2 - Diesel Engine Driven Generators Submittal Rev. 1 - FWT Updates
(mjs) AHA Response - 2015-02-09.pdf
Caterpillar - 2500 kW G24 - G25 204
G24-G27_ 263213-03-03 - Diesel Engine Driven
Generators - Record Product Data - AHA, Maffei,
Acentech Review - 2020-04-02.pdf
849, 851 G24-G27_ 263213-03-03 - Diesel Engine Driven
Generators - Record Product Data - AHA, Maffei,
Acentech Review - 2020-04-02.pdf
Caterpillar - 2000 kW G26 - G27 13
G24-G27_ 263213-03-03 - Diesel Engine Driven Generators - Record Product Data - AHA, Maffei,
Acentech Review - 2020-04-02.pdf
848, 850 G24-G27_ 263213-03-03 - Diesel Engine Driven Generators - Record Product Data - AHA, Maffei,
Acentech Review - 2020-04-02.pdf
Caterpillar - 2000 kW
G15 - G16
G19 - G22
G28 - G29
50 G15, G16, G19-22_ eBay SLC03 Phase 1 Class B
3516C Generators - Submittal - Revision E.pdf 18, 38 G15, G16, G19-22_ eBay SLC03 Phase 1 Class B
3516C Generators - Submittal - Revision E.pdf
Caterpillar - 1500 kW G17 - G18 59, 60
G17, G18_ eBay SLC03 - 3512C Standby Generators -
Submittal - Revision E(1) - RGV (includes discharge
hood extension).pdf
15, 47 G17, G18_ eBay SLC03 - 3512C Standby Generators -
Submittal - Revision E(1) - RGV (includes discharge
hood extension).pdf
Caterpillar - 1000 kW G23 63
G23_ eBay SLC03 - C32 Standby Generator - Submittal - Revision E - UPDATED - RGV.pdf 12, 54, 78 G23_ eBay SLC03 - C32 Standby Generator - Submittal - Revision E - UPDATED - RGV.pdf
Caterpillar - 750 kW G32 - G33 31-32
G32_ SLC03-PH3-263213.001.0_Class A Generator -
AHA Response - 2023-03-15.pdf 7, 30 G32_ SLC03-PH3-263213.001.0_Class A Generator -
AHA Response - 2023-03-15.pdf
Caterpillar - 100 kW FP1 1
Emissions Information CAT D4B01369 100kW
Genset.pdf N/A N/A
John Deere - 64 kW FP2 9 John Deere Engine.pdf N/A N/A
Appendix 3
eBay Generator Rating and Emission Factor Page Numbers
eBay SLC Data Center
South Jordan, UT
# Confidential
Notice of Intent Application eBay SLC Data Center
Ramboll
Confidential
APPENDIX 4
POTENTIAL EMISSIONS CALCULATIONS
Table 1
Facility-Wide Potential Emissions
Existing Emergency
Generators
Cooling
Towers
NOX 45.55 --45.55 70 No
CO 6.68 --6.68 100 No
VOC 1.44 --1.44 50 No
PM 0.65 3.04 3.70 100 No
PM10 0.65 2.29 2.94 100 No
PM2.5 0.65 6.84E-03 0.66 70 No
SO2 0.056 --0.056 70 No
Maximum Individual
HAP (Benzene)0.0048 --0.0048 10 No
Total HAP 0.035 --0.035 25 No
CO2e 3,669.63 --3669.63 ----
Notes:
1.
2.
3.Utah Administrative Code. R307-403. Permit: New and Modified Sources in Nonattainment Areas and Maintenance Areas.
https://rules.utah.gov/publicat/code/r307/r307-403.htm#E2.
UAC R307-420 applies when Salt Lake County is designated as a maintenance area with respect to the 2015 8-hr Ozone
National Ambient Air Quality Standard (NAAQS). Salt Lake County is currently classified as Marginal nonattainment for
the Ozone standard. However, UAC does not have regulations codified for when Salt Lake County is designated as
nonattainment, and therefore, the Major Source classification for VOC from UAC R307-420 was used.
Refer to the definition of "Major Source" found in Rule R307-101 of the Utah Administrative Code. The Major Source
thresholds for NOX, VOC, PM10, PM2.5, and SO2 have been set in Rule R307-420 in accordance with the severity of the
surrounding nonattainment areas consistent with the relevant section of the Clean Air Act. Please note, in some cases
these pollutants are regulated as precursor pollutants to the pollutant for which Salt Lake County has been designated
with "nonattainment" status. Note the major source threshold for NOX in Salt Lake County will drop to 50 tpy in January
2025.
Pollutant Above Threshold?
Major Source
Threshold2,3
(tpy)
Facility-Wide Potential
Annual Emissions
(tpy)
Potential Annual Emissions1
(tpy)
# Confidential
Generators G1-G22, G26-G27
2 Number of Generator Engines
G1-G7 (3.25 MW) Engines 7
G8-G14 (3.1 MW) Engines 7
2
6
G17-G18 (1.5 MW) Engines 2
3 Power Output by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
G1-G7 ----------341 854 1,707 2,561 3,415
G8-G14 548 1,118 2,068 3,019 3,969 ----------
G15-G16; G19-G22; G26-
G27 359 732 1,327 1,930 2,563 ----------
G17-G18 260 527 953 1,385 1,838 ----------
Notes:
1.
4 Fuel Consumption by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
G1-G7 ----133.0 192.0 237.0 3.21 8.01 16.03 24.04 32.06
G8-G14 44.9 80.6 130.4 165.3 214.2 6.15 11.04 17.87 22.65 29.35
G15-G16; G19-G22; G26-
G27 26.4 44.8 77.5 107.5 138.0 3.62 6.14 10.62 14.73 18.91
G17-G18 19.7 33.9 58.0 82.0 104.6 2.70 4.65 7.95 11.24 14.33
Notes:
1.
2.
7,000 Btu/hp-hr
1.341 hp/kWm
3.
Diesel HHV =0.137 MMBtu/gal
Per the manufacturer specification sheets and performance data for each engine model.
Engines Group
Power Output (bhp/engine) 1 Power Output (kWm/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
Heat Input
(MMBtu/hr/engine) 2,3
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
G1-G7 diesel fuel consumption was not available from manufacturer specification sheets. Heat Input was calculated using conversion factors from USEPA's AP-42,
Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, Table 3.4-1, footnote e (October 1996) and Appendix-A:
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All
Stationary Dual-fuel Engines, Table 3.4-1, footnote a (October 1996):
G19-G22; G26-G27 (2.0 MW) Engines
G15-G16 (2.0 MW) Engines
# Confidential
5 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
NOX --6.20 6.00 7.00 8.70 5.76 3.05 4.08 6.40 7.28
CO --3.80 1.70 1.20 1.30 5.84 4.41 1.54 1.93 1.31
VOC2 --0.90 0.55 0.32 0.23 2.13 0.83 0.46 0.18 0.15
Filterable PM3 --0.44 0.210 0.090 0.070 0.56 0.33 0.09 0.07 0.05
Notes:
1.
2.
3.
6 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
NOX 7.13 5.03 3.82 4.67 6.56 9.14 5.85 4.26 4.41 6.58
CO 4.36 2.11 0.59 0.39 0.54 6.13 3.13 1.47 0.71 0.87
VOC2 1.08 0.49 0.34 0.23 0.14 1.06 0.45 0.32 0.23 0.16
Filterable PM3 0.49 0.31 0.080 0.040 0.040 0.36 0.29 0.13 0.06 0.04
Notes:
1.
2.
3.
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated
Speed Potential Site Variation" (i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Pollutant
Uncontrolled Emission Factors for G15-G16; G19-G22; G26-
G27 Engines (g/bhp-hr) 1
Uncontrolled Emission Factors for G17-G18 Engines
(g/bhp-hr) 1
Pollutant
Uncontrolled Emission Factors for G1-G7 Engines
(g/kW-hr) 1
Uncontrolled Emission Factors for G8-G14 Engines
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated
Speed Potential Site Variation" (i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
# Confidential
7 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.PAH = Polycyclic Aromatic Hydrocarbons
8 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
Pollutant Emission Factor
(lb/MMBtu)1
2.12E-04
7.88E-06
2.52E-05Acetaldehyde
Acrolein
Total PAH3
SO22
Condensable PM
Benzene
Toluene
Xylenes
Formaldehyde 7.89E-05
1.93E-04
2.81E-04
7.76E-04
7.70E-03
1.52E-03
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
Pollutant Emission Factor
(lb/MMBtu)1
163.61
1.32E-03
6.61E-03
163.05
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
# Confidential
9 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX --11.67 22.59 39.52 65.50 65.50 6.96 7.52 18.60 42.59 63.70 63.70
CO --7.15 6.40 6.78 9.79 9.79 7.06 10.87 7.02 12.84 11.46 12.84
VOC --1.69 2.07 1.81 1.73 2.07 2.57 2.05 2.10 1.20 1.31 2.57
PM/PM10/PM2.54 --0.89 0.91 0.69 0.77 0.91 0.72 0.90 0.55 0.64 0.66 0.90
SO2 --0.012 0.024 0.036 0.049 0.049 0.009 0.017 0.027 0.034 0.044 0.044
Hazardous Air Pollutants
Benzene 2.49E-03 6.22E-03 1.24E-02 1.87E-02 2.49E-02 2.49E-02 4.77E-03 8.57E-03 1.39E-02 1.76E-02 2.28E-02 2.28E-02
Toluene 9.01E-04 2.25E-03 4.50E-03 6.76E-03 9.01E-03 9.01E-03 1.73E-03 3.10E-03 5.02E-03 6.36E-03 8.25E-03 8.25E-03
Xylenes 6.19E-04 1.55E-03 3.09E-03 4.64E-03 6.19E-03 6.19E-03 1.19E-03 2.13E-03 3.45E-03 4.37E-03 5.66E-03 5.66E-03
Formaldehyde 2.53E-04 6.32E-04 1.26E-03 1.90E-03 2.53E-03 2.53E-03 4.85E-04 8.71E-04 1.41E-03 1.79E-03 2.32E-03 2.32E-03
Acetaldehyde 8.08E-05 2.02E-04 4.04E-04 6.06E-04 8.08E-04 8.08E-04 1.55E-04 2.78E-04 4.50E-04 5.71E-04 7.40E-04 7.40E-04
Acrolein 2.53E-05 6.31E-05 1.26E-04 1.89E-04 2.53E-04 2.53E-04 4.85E-05 8.70E-05 1.41E-04 1.78E-04 2.31E-04 2.31E-04
Total PAH 6.80E-04 1.70E-03 3.40E-03 5.10E-03 6.80E-03 6.80E-03 1.30E-03 2.34E-03 3.79E-03 4.80E-03 6.22E-03 6.22E-03
Total HAP 5.05E-03 1.26E-02 2.52E-02 3.78E-02 5.05E-02 5.05E-02 9.68E-03 1.74E-02 2.81E-02 3.57E-02 4.62E-02 4.62E-02
Greenhouse Gases
CO2 522.67 1,306.67 2,613.35 3,920.02 5,226.70 5,226.70 1,003.21 1,800.87 2,913.56 3,693.34 4,785.93 4,785.93
CH4 0.02 0.05 0.11 0.16 0.21 0.21 0.04 0.07 0.12 0.15 0.19 0.19
N2O 0.00 0.01 0.02 0.03 0.04 0.04 0.008 0.015 0.024 0.030 0.039 0.04
CO2e 524.46 1,311.16 2,622.32 3,933.47 5,244.63 5,244.63 1,006.66 1,807.05 2,923.56 3,706.02 4,802.35 4,802.35
Notes:
1.
2.
3.
4.
G8-G14 Engines - Hourly Emissions
(lb/hr/engine) 2, 3
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/gen) = Emission Factor at Load X (g/kWm-hr) x Engine Power at Load X (kWm/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
Pollutant
G1-G7 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
# Confidential
10 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX 5.64 8.12 11.18 19.87 37.06 37.06 5.24 6.79 8.95 13.47 26.67 26.67
CO 3.45 3.41 1.73 1.66 3.05 3.45 3.51 3.63 3.09 2.17 3.53 3.63
VOC 0.85 0.79 0.99 0.98 0.79 0.99 0.61 0.52 0.67 0.70 0.65 0.70
PM/PM10/PM2.54 0.42 0.55 0.32 0.28 0.37 0.55 0.23 0.37 0.33 0.27 0.27 0.37
SO2 0.005 0.009 0.016 0.022 0.029 0.029 0.004 0.007 0.012 0.017 0.022 0.022
Hazardous Air Pollutants
Benzene 2.81E-03 4.76E-03 8.24E-03 1.14E-02 1.47E-02 1.47E-02 2.09E-03 3.60E-03 6.17E-03 8.72E-03 1.11E-02 1.11E-02
Toluene 1.02E-03 1.73E-03 2.98E-03 4.14E-03 5.31E-03 5.31E-03 7.59E-04 1.31E-03 2.23E-03 3.16E-03 4.03E-03 4.03E-03
Xylenes 6.98E-04 1.18E-03 2.05E-03 2.84E-03 3.65E-03 3.65E-03 5.21E-04 8.97E-04 1.53E-03 2.17E-03 2.77E-03 2.77E-03
Formaldehyde 2.85E-04 4.84E-04 8.38E-04 1.16E-03 1.49E-03 1.49E-03 2.13E-04 3.67E-04 6.27E-04 8.87E-04 1.13E-03 1.13E-03
Acetaldehyde 9.12E-05 1.55E-04 2.68E-04 3.71E-04 4.77E-04 4.77E-04 6.80E-05 1.17E-04 2.00E-04 2.83E-04 3.61E-04 3.61E-04
Acrolein 2.85E-05 4.84E-05 8.37E-05 1.16E-04 1.49E-04 1.49E-04 2.13E-05 3.66E-05 6.26E-05 8.85E-05 1.13E-04 1.13E-04
Total PAH 7.67E-04 1.30E-03 2.25E-03 3.12E-03 4.01E-03 4.01E-03 5.72E-04 9.85E-04 1.68E-03 2.38E-03 3.04E-03 3.04E-03
Total HAP 5.69E-03 9.66E-03 1.67E-02 2.32E-02 2.98E-02 2.98E-02 4.25E-03 7.31E-03 1.25E-02 1.77E-02 2.26E-02 2.26E-02
Greenhouse Gases
CO2 589.86 1,000.98 1,731.60 2,401.90 3,083.37 3,083.37 440.16 757.44 1,295.91 1,832.15 2,337.11 2,337.11
CH4 0.02 0.04 0.07 0.10 0.13 0.13 0.02 0.03 0.05 0.07 0.09 0.09
N2O 0.005 0.008 0.014 0.019 0.025 0.03 0.004 0.006 0.011 0.015 0.019 0.02
CO2e 591.89 1,004.41 1,737.55 2,410.14 3,093.95 3,093.95 441.67 760.04 1,300.36 1,838.44 2,345.13 2,345.13
Notes:
1.
2.
3.Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
Pollutant
G15-G16; G19-G22; G26-G27 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
G17-G18 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
# Confidential
11 Potential to Emit - All Pollutants
Pollutant
Maximum Engine
Operation
(hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.5
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
308.34
2.98E-03
4.01E-04
1.49E-05
4.77E-05
1.49E-04
Potential Annual
Emissions G1-G7
(tpy)
Potential Annual
Emissions G8-G14
(tpy)
Potential Annual
Emissions G15-G16
(tpy)
Potential Annual
Emissions G19-G22;
G26-27
(tpy)
60 60 100 60
Potential Annual
Emissions G17-G18
(tpy)
60
0.01
0.34
3.71
3.65E-04
5.31E-04
1.47E-03
0.54
1,101.37
0.009
0.04
1,097.61
1.43E-03
5.30E-05
1.55E-04
4.86E-04
1.19E-03
1.06E-02
1,008.49
0.008
0.04
1,005.05
9.70E-03
1.31E-03
4.86E-05
309.40
1.30E-03
6.67E-04
2.42E-04
1.66E-04
6.79E-05
2.17E-05
0.19
0.43
0.0029
0.055
0.099
0.01
0.10
0.18 0.04
0.02
1.70E-04
5.31E-04
1.30E-03
1.89E-03
5.22E-03
0.01
0.19
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above)
for each engine grouping conservatively assuming the maximum annual operating rate shown for each engine group.
8.58E-05
7.22E-04
2.69E-04
6.57E-04
9.56E-04
2.64E-03
556.91
0.005
0.02
555.01
5.36E-03
2.68E-05 6.78E-06
1.82E-04
1.35E-03
140.71
0.001
0.01
140.23
1.73E-03
4.78E-03
0.00
0.01
0.62
6.67
2.06
13.75 1.60
0.222.70
13.38
# Confidential
Generators G23-G25, FP1, FP2
12 Number of Generator Engines
FP1 (100 kW) Engine 1
FP2 (64 kW) Engine 1
1
G24-G25 (2.5 MW) Engines 2
13 Power Output by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
FP1 ------------------100
FP2 --------86 ----------
G23 180 368 669 977 1,290 ----------
G24-G25 417 864 1,587 2,318 3,052 ----------
Notes:
1.
14 Fuel Consumption by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
FP1 ------------------0.94
FP2 --------4.5 --------0.62
G23 12.5 21.8 38.2 56.4 71.9 1.71 2.99 5.23 7.73 9.85
G24-G25 32.2 57.1 96.5 133.8 175.0 4.41 7.82 13.22 18.33 23.98
Notes:
1.
2.
7,000 Btu/hp-hr
1.3407 hp/kWe
3.
Diesel HHV =0.137 MMBtu/gal
Heat Input
(MMBtu/hr/engine) 2,3
G23 (1.0 MW) Engine
Per the manufacturer specification sheets and performance data for each engine model.
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
G1-G7 diesel fuel consumption was not available from manufacturer specification sheets. Heat Input was calculated using conversion factors from USEPA's AP-42, Chapter 3.4, Large Stationary
Diesel and All Stationary Dual-fuel Engines, Table 3.4-1, footnote e (October 1996) and Appendix-A:
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines,
Table 3.4-1, footnote a (October 1996):
Engines Group Power Output (bhp/engine) 1 Power Output (kWe/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
# Confidential
15 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
NOX --------3.52 --------3.06
CO --------1.15 --------0.60
VOC2 --------0.21 --------0.16
Filterable PM3 --------0.21 --------0.17
Notes:
1.
2.
3.
16 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full Standby 10% Load 25% Load 50% Load 75% Load Full Standby
NOX 6.43 5.34 4.37 4.60 5.97 6.83 3.74 4.02 5.36 6.77
CO 6.03 1.91 0.64 0.21 0.24 5.00 1.99 0.65 0.62 0.88
VOC2 0.73 0.18 0.13 0.09 0.02 0.83 0.40 0.26 0.18 0.11
Filterable PM3 0.40 0.25 0.09 0.03 0.04 0.24 0.22 0.07 0.04 0.04
Notes:
1.
2.
3.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Pollutant
Pollutant
Uncontrolled Emission Factors for FP1 Engine
(g/kW-hr) 1
Uncontrolled Emission Factors for FP2 Engine
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation"
(i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Uncontrolled Emission Factors for G23 Engine
(g/bhp-hr) 1
Uncontrolled Emission Factors for G24-G25 Engines
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation"
(i.e., not-to-exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
# Confidential
17 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.
4.
18 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
1.93E-04
2.81E-04
7.76E-04
7.70E-03
(lb/MMBtu)3
Benzene
Toluene
Xylenes
0.291.52E-03SO2
Condensable PM
Pollutant
Emission Factor
(>600 hp)
Emission Factor
(≤600 hp)
(lb/MMBtu)1,2
2.85E-04
4.09E-04
9.33E-04
7.70E-03
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
Emission factors are from the U.S. EPA's AP-42, Chapter 3.3, Gasoline and Diesel Industrial Engines, Table 3.3-2 (October 1996). It was conservatively assumed the condensable PM factor for
engines >600 hp is equivalent to engines ≤600 hp.
PAH = Polycyclic Aromatic Hydrocarbons
Pollutant Emission Factor
(lb/MMBtu)1
1,3-Butadiene
Formaldehyde
Acetaldehyde
Acrolein
Total PAH4
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
1.68E-04
9.25E-05
7.67E-04
1.18E-03
3.91E-05
2.12E-04
7.88E-06
2.52E-05
7.89E-05
--
163.05
6.61E-03
1.32E-03
163.61
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
# Confidential
19 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX --------0.78 0.78 --------0.58 0.58
CO --------0.25 0.25 --------0.11 0.11
VOC --------0.05 0.05 --------0.03 0.03
PM/PM10/PM2.54 --------0.05 0.05 --------0.04 0.04
SO2 --------0.27 0.27 --------0.18 0.18
Hazardous Air Pollutants
Benzene --------8.76E-04 8.76E-04 --------5.75E-04 5.75E-04
Toluene --------3.84E-04 3.84E-04 --------2.52E-04 2.52E-04
Xylenes --------2.67E-04 2.67E-04 --------1.76E-04 1.76E-04
1,3-Butadiene --------3.67E-05 3.67E-05 --------2.41E-05 2.41E-05
Formaldehyde --------1.11E-03 1.11E-03 --------7.28E-04 7.28E-04
Acetaldehyde --------7.20E-04 7.20E-04 --------4.73E-04 4.73E-04
Acrolein --------8.68E-05 8.68E-05 --------5.70E-05 5.70E-05
Total PAH --------1.58E-04 1.58E-04 --------1.04E-04 1.04E-04
Total HAP --------0.00E+00 3.64E-03 --------0.00E+00 2.39E-03
Greenhouse Gases
CO2 --------153.02 153.02 --------100.54 100.54
CH4 --------0.01 0.01 --------0.00 0.00
N2O --------0.00 0.00 --------0.001 0.00
CO2e --------153.55 153.55 --------100.89 100.89
Notes:
1.
2.
3.
4.
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/gen) = Emission Factor at Load X (g/kWm-hr) x Engine Power at Load X (kWm/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
Pollutant
FP1 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
FP2 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
# Confidential
20 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX 2.56 4.33 6.45 9.90 16.98 16.98 6.29 7.13 14.06 27.40 45.55 45.55
CO 2.40 1.55 0.94 0.45 0.68 2.40 4.60 3.79 2.27 3.17 5.92 5.92
VOC 0.29 0.15 0.19 0.19 0.06 0.29 0.76 0.76 0.91 0.92 0.74 0.92
PM/PM10/PM2.54 0.17 0.23 0.17 0.12 0.19 0.23 0.25 0.48 0.35 0.35 0.45 0.48
SO2 0.003 0.005 0.008 0.012 0.015 0.015 0.007 0.012 0.020 0.028 0.036 0.036
Hazardous Air Pollutants
Benzene 1.33E-03 2.32E-03 4.06E-03 6.00E-03 7.65E-03 7.65E-03 3.42E-03 6.07E-03 1.03E-02 1.42E-02 1.86E-02 1.86E-02
Toluene 4.81E-04 8.39E-04 1.47E-03 2.17E-03 2.77E-03 2.77E-03 1.24E-03 2.20E-03 3.72E-03 5.15E-03 6.74E-03 6.74E-03
Xylenes 3.31E-04 5.77E-04 1.01E-03 1.49E-03 1.90E-03 1.90E-03 8.52E-04 1.51E-03 2.55E-03 3.54E-03 4.63E-03 4.63E-03
Formaldehyde 1.35E-04 2.36E-04 4.13E-04 6.10E-04 7.77E-04 7.77E-04 3.48E-04 6.17E-04 1.04E-03 1.45E-03 1.89E-03 1.89E-03
Acetaldehyde 4.32E-05 7.53E-05 1.32E-04 1.95E-04 2.48E-04 2.48E-04 1.11E-04 1.97E-04 3.33E-04 4.62E-04 6.04E-04 6.04E-04
Acrolein 1.35E-05 2.35E-05 4.12E-05 6.09E-05 7.76E-05 7.76E-05 3.48E-05 6.17E-05 1.04E-04 1.44E-04 1.89E-04 1.89E-04
Total PAH 3.63E-04 6.33E-04 1.11E-03 1.64E-03 2.09E-03 2.09E-03 9.35E-04 1.66E-03 2.80E-03 3.89E-03 5.08E-03 5.08E-03
Total HAP 2.70E-03 4.70E-03 8.24E-03 1.22E-02 1.55E-02 1.55E-02 6.94E-03 1.23E-02 2.08E-02 2.89E-02 3.77E-02 3.77E-02
Greenhouse Gases
CO2 279.29 487.08 853.51 1,260.16 1,606.48 1,606.48 719.45 1,275.80 2,156.13 2,989.53 3,910.07 3,910.07
CH4 0.01 0.02 0.03 0.05 0.07 0.07 0.03 0.05 0.09 0.12 0.16 0.16
N2O 0.002 0.004 0.007 0.010 0.013 0.01 0.006 0.010 0.017 0.024 0.032 0.03
CO2e 280.25 488.75 856.44 1,264.49 1,611.99 1,611.99 721.92 1,280.18 2,163.52 2,999.79 3,923.49 3,923.49
Notes:
1.
2.
3.
Pollutant
G23 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
G24-G25 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
# Confidential
21 Potential to Emit - All Pollutants
Pollutant
Maximum Engine
Operation (hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.54
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
60
0.0022
0.029
0.055
0.36
2.7
100
Potential Annual Emissions FP1
(tpy)
Potential Annual Emissions FP2
(tpy)
100 60
Potential Annual Emissions G23
(tpy)
Potential Annual Emissions G24-
G25
(tpy)
0.014
0.0027
0.0023
0.013
0.039 0.51
0.0089
0.0018
0.0015
0.0057
0.029
2.8E-04
0
4.0E-04
0.0011
4.7E-04
6.3E-05
2.3E-06
7.4E-06
2.3E-05
0
0.0023
3.1E-04
1.1E-05
3.6E-05
1.1E-04
4.5E-04
0.0068
0.009
0.072
5.5E-05
1.8E-06
1.3E-05
1.9E-05
5.7E-05
8.3E-05
2.3E-04
1.2E-04
5.2E-06
2.9E-06
2.4E-05
3.6E-05
1.2E-06
8.8E-06
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above) for each
engine grouping conservatively assuming the maximum annual operating rate shown for each engine group.
4.1E-05
2.0E-04
5.0
7.7
6.2E-05
3.1E-04
7.7
4.4E-05
235
0.0019
0.010
235
48
3.9E-04
0.0020
48
5.0
1.3E-05
2.9E-05
1.8E-04
7.9E-06
4.3E-06
3.6E-05
# Confidential
Generators G28-29, 32-33
22 Number of Generator Engines
G28-G29 (2.0 MW) Engines 2
G32-G33 (750 kW) Engines 2
23 Power Output by Load
10% Load 25% Load 50% Load 75% Load Full
Standby
G28-G29 359 732 1,327 1,930 2,563
G32-G33 153 318 578 843 1,114
Notes:
1.
24 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
G28-G29 26.4 44.8 77.5 107.5 138.0 3.62 6.14 10.62 14.73 18.91
G32-G33 9.6 16.7 28.7 41.4 52.5 1.32 2.29 3.93 5.67 7.19
Notes:
1.
2.
Diesel HHV =0.137 MMBtu/gal
25 Uncontrolled Emission Factors by Load
10% Load 25% Load 50% Load 75% Load Full
Standby 10% Load 25% Load 50% Load 75% Load Full
Standby
NOX 7.13 5.03 3.82 4.67 6.56 7.41 5.37 4.31 4.64 6.16
CO 4.36 2.11 0.59 0.39 0.54 3.80 1.68 1.12 0.83 0.48
VOC2 1.08 0.49 0.34 0.23 0.14 0.71 0.28 0.17 0.10 0.05
Filterable PM3 0.49 0.31 0.08 0.04 0.04 0.46 0.33 0.28 0.08 0.04
Notes:
1.
2.
3.
Engines Group Power Output (bhp/engine) 1
Engines Group
Diesel Fuel Consumption
(gal/hr/engine) 1
Heat Input
(MMBtu/hr/engine) 2
Uncontrolled Emission Factors for G32-G33 Engine
(g/bhp-hr) 1
Refer to enclosed manufacturer performance data for each engine model. Emission factors are conservatively based on the manufacturer's not-to-exceed or "Rated Speed Potential Site Variation" (i.e., not-to-
exceed equivalent) emissions data.
Assumes that all hydrocarbons (HC) are VOC.
Assumes that all filterable PM is less than 2.5 microns in diameter (i.e., PM = PM10 = PM2.5).
Per the manufacturer specification sheets and performance data for each engine model.
Refer to enclosed manufacturer specification sheets and performance data for each engine model.
Diesel fuel consumption was converted to heat input based on the diesel high heating value from the USEPA's AP-42, Chapter 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, Table 3.4-1,
footnote a (October 1996):
Pollutant
Uncontrolled Emission Factors for G28-G29 Engines (g/bhp-hr) 1
# Confidential
26 AP-42 Emission Factors
Notes:
1.
2.
Diesel Sulfur Content =0.0015 wt.% Sulfur
3.PAH = Polycyclic Aromatic Hydrocarbons
27 GHG Emission Factors
CO2
CH4
N2O
CO2e2
Notes:
1.
2.
CO2:1
CH4:25
N2O:298
Pollutant Emission Factor
(lb/MMBtu)1
Total PAH3
7.76E-04
7.70E-03
1.52E-03SO22
Condensable PM
Benzene
2.12E-04
7.88E-06
2.52E-05
7.89E-05
1.93E-04
2.81E-04Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Emission factors are from the U.S. EPA's AP-42, Chapter 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines, Tables 3.4-1, 3.4-2, 3.4-3, and 3.4-4 (October 1996).
The SO2 emission factor was calculated based on the maximum allowable diesel fuel sulfur content under NSPS Subpart IIII:
Pollutant Emission Factor
(lb/MMBtu)1
163.61
1.32E-03
6.61E-03
163.05
Per 40 CFR 98, Subpart C, Tables C-1 and C-2 for No. 2 fuel oil combustion. The emission factors were converted from kg/MMBtu to lb/MMBtu.
The CO2e emission factor is calculated as the sum of each GHG pollutant multiplied by its global warming potential, per 40 CFR 98, Subpart A, Table A-1:
# Confidential
28 Hourly Emission Rates
10% Load 25% Load 50% Load 75% Load Full
Standby Maximum 10% Load 25% Load 50% Load 75% Load Full
Standby Maximum
Criteria Pollutants
NOX 5.64 8.12 11.18 19.87 37.06 37.06 2.50 3.76 5.49 8.62 15.13 15.13
CO 3.45 3.41 1.73 1.66 3.05 3.45 1.28 1.18 1.43 1.54 1.18 1.54
VOC 0.85 0.79 0.99 0.98 0.79 0.99 0.24 0.20 0.22 0.19 0.12 0.24
PM/PM10/PM2.54 0.42 0.55 0.32 0.28 0.37 0.55 0.17 0.25 0.39 0.19 0.15 0.39
SO2 0.005 0.009 0.016 0.022 0.029 0.029 0.002 0.003 0.006 0.009 0.011 0.011
Hazardous Air Pollutants
Benzene 2.81E-03 4.76E-03 8.24E-03 1.14E-02 1.47E-02 1.47E-02 1.02E-03 1.78E-03 3.05E-03 4.40E-03 5.58E-03 5.58E-03
Toluene 1.02E-03 1.73E-03 2.98E-03 4.14E-03 5.31E-03 5.31E-03 3.70E-04 6.43E-04 1.11E-03 1.59E-03 2.02E-03 2.02E-03
Xylenes 6.98E-04 1.18E-03 2.05E-03 2.84E-03 3.65E-03 3.65E-03 2.54E-04 4.42E-04 7.59E-04 1.09E-03 1.39E-03 1.39E-03
Formaldehyde 2.85E-04 4.84E-04 8.38E-04 1.16E-03 1.49E-03 1.49E-03 1.04E-04 1.81E-04 3.10E-04 4.48E-04 5.68E-04 5.68E-04
Acetaldehyde 9.12E-05 1.55E-04 2.68E-04 3.71E-04 4.77E-04 4.77E-04 3.32E-05 5.77E-05 9.91E-05 1.43E-04 1.81E-04 1.81E-04
Acrolein 2.85E-05 4.84E-05 8.37E-05 1.16E-04 1.49E-04 1.49E-04 1.04E-05 1.80E-05 3.10E-05 4.47E-05 5.67E-05 5.67E-05
Total PAH 7.67E-04 1.30E-03 2.25E-03 3.12E-03 4.01E-03 4.01E-03 2.79E-04 4.85E-04 8.34E-04 1.20E-03 1.53E-03 1.53E-03
Total HAP 5.69E-03 9.66E-03 1.67E-02 2.32E-02 2.98E-02 2.98E-02 2.07E-03 3.60E-03 6.19E-03 8.93E-03 1.13E-02 1.13E-02
Greenhouse Gases
CO2 589.86 1,000.98 1,731.60 2,401.90 3,083.37 3,083.37 214.50 373.13 641.25 925.01 1,173.02 1,173.02
CH4 0.02 0.04 0.07 0.10 0.13 0.13 0.01 0.02 0.03 0.04 0.05 0.05
N2O 0.005 0.008 0.014 0.019 0.025 0.03 0.002 0.003 0.005 0.008 0.010 0.01
CO2e 591.89 1,004.41 1,737.55 2,410.14 3,093.95 3,093.95 215.23 374.41 643.45 928.19 1,177.05 1,177.05
Notes:
1.
2.
3.
For engine-specific emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor at Load X (g/hp-hr) x Engine Power at Load X (bhp/engine) / (453.6 g/lb)
Pollutant
G28-G29 Engines - Hourly Emissions
(lb/hr/engine) 1, 2
G32-G33 Engine - Hourly Emissions
(lb/hr/engine) 1, 2
For AP-42 & GHG emission factors:
Hourly Emissions at Load X (lb/hr/engine) = Emission Factor (lb/MMBtu) x Heat Input at Load X (MMBtu/hr/engine)
Total PM/PM10/PM2.5 is the sum of filterable PM/PM10/PM2.5 and condensable PM.
# Confidential
29 Potential to Emit - All Pollutants
Pollutant
Maximum
Engine
Operation
(hr/yr/engine)
Criteria Pollutants
NOX
CO
VOC
PM/PM10/PM2.5
SO2
Hazardous Air Pollutants
Benzene
Toluene
Xylenes
Formaldehyde
Acetaldehyde
Acrolein
Total PAH
Total HAP
Greenhouse Gases
CO2
CH4
N2O
CO2e
Notes:
1.
6.5E-04
0.023
0.014
0.09
0.9
0.0017
0.033
0.060
2.2
60
Potential Annual Emissions G32-
G33
(tpy)
60
Potential Annual Emissions G28-
G29
(tpy)
186
0.0015
0.0075
185
0.21
8.3E-05
71
5.7E-04
0.0029
70
Total potential annual emissions of all pollutants were based on the maximum hourly emission rate (as determined using the emissions data summarized above) for each engine grouping conservatively
assuming the maximum annual operating rate shown for each engine group.
1.2E-04
3.3E-04
0.0018
2.4E-04
8.9E-06
2.9E-05
9.0E-05
2.2E-04
3.2E-04
0.0009
6.8E-04
9.2E-05
3.4E-06
1.1E-05
3.4E-05
# Confidential
SLC01 COOLING TOWER PM10 AND PM2.5 EMISSIONS
1)Using Drift Particle Size Analysis, Determine the Percent of Drift
that Results as PM10 and PM2.5 after Evaporation:
Assumptions:
Assume PM10 density = 2.2 g/cm3 =2.2E-06 ug/um3
Assume H2O density = 1 g/cm3 =0.000001 ug/um3
Circulating Water TDS = 1330 ppm (Input Value)
(Total Dissolved Solids)
Calculational Method Applied to Determine Particle Size After Evaporation of Water:Interpolate Interpolate
EPRI*to find mass to find mass
Droplet Droplet Droplet Particle Particle Particle EPRI Mass percent of percent of
Diam Vol Mass Mass Vol Diam % Mass Fraction PM10:PM2.5:
(um)(um^3)(ug)(ug)(um^3)(um)Smaller in bin
10 524 0.0005 0.00000 0.32 0.85 0.000 0.0000 0.85
20 4189 0.0042 0.00001 2.53 1.69 0.196 0.1960 1.69
30 14137 0.0141 0.00002 8.55 2.54 0.226 0.0300 2.54 0.22
40 33510 0.0335 0.00004 20.26 3.38 0.514 0.2880 3.38
50 65450 0.0654 0.00009 39.57 4.23 1.816 1.3020 4.23
60 113097 0.1131 0.00015 68.37 5.07 5.702 3.8860 5.07
70 179594 0.1796 0.00024 108.57 5.92 21.348 15.6460 5.92
90 381704 0.3817 0.00051 230.76 7.61 49.812 28.4640 7.61
110 696910 0.6969 0.00093 421.31 9.30 70.509 20.6970 9.30
130 1150347 1.1503 0.00153 695.44 10.99 82.023 11.5140 10.99 75.27
150 1767146 1.7671 0.00235 1068.32 12.68 88.012 5.9890 12.68
180 3053628 3.0536 0.00406 1846.06 15.22 91.032 3.0200 15.22
210 4849048 4.8490 0.00645 2931.47 17.76 92.468 1.4360 17.76
240 7238229 7.2382 0.00963 4375.84 20.29 94.091 1.6230 20.29
270 10305995 10.3060 0.01371 6230.44 22.83 94.689 0.5980 22.83
300 14137167 14.1372 0.01880 8546.56 25.37 96.288 1.5990 25.37
350 22449298 22.4493 0.02986 13571.62 29.59 97.011 0.7230 29.59
400 33510322 33.5103 0.04457 20258.51 33.82 98.340 1.3290 33.82
450 47712938 47.7129 0.06346 28844.64 38.05 99.071 0.7310 38.05
500 65449847 65.4498 0.08705 39567.41 42.28 99.071 0.0000 42.28
600 113097336 113.0973 0.15042 68372.48 50.73 100.000 0.9290 50.73
*EPRI Data - Test Cell, Drift Efficiency = 0.0003%
2)
Circulating Water Rate:20,520 gpm (Input Value)
Drift Rate:0.005 %(Input Value)
Hours per year operation:8760 hr/yr (Input Value)
Total PM =0.68 lb/hr
(On annual basis =)2.99 tpy
3)Multiply Total PM by PM10 fraction to obtain PM10 emissions:
0.68 x 0.7527 =0.514 lb/hr PM10
or,2.25 tpy
4)Multiply Total PM by PM2.5 fraction to obtain PM2.5 emissions:
0.68 x 0.0022 =0.002 lb/hr PM10
or,0.007 tpy
Reference: Joel Reisman et al, 2002. Calculating Realistic PM10 Emissions from Cooling Towers. Environmental Progress,
Volume 21, Issue 2, pages 127–130, July 2002
# Confidential
SLC02 PHASE 1 COOLING TOWER PM10 AND PM2.5 EMISSIONS
1)Using Drift Particle Size Analysis, Determine the Percent of Drift
that Results as PM10 and PM2.5 after Evaporation:
Assumptions:
Assume PM10 density = 2.2 g/cm3 =0.0000022 ug/um3
Assume H2O density = 1 g/cm3 =0.000001 ug/um3
Circulating Water TDS = 1330 ppm (Input Value)
(Total Dissolved Solids)
Calculational Method Applied to Determine Particle Size After Evaporation of Water:Interpolate Interpolate
EPRI*to find mass to find mass
Droplet Droplet Droplet Particle Particle Particle EPRI Mass percent of percent of
Diam Vol Mass Mass Vol Diam % Mass Fraction PM10:PM2.5:
(um)(um^3)(ug)(ug)(um^3)(um)Smaller in bin
10 524 0.0005 0.00000 0.32 0.85 0.000 0.0000 0.85
20 4189 0.0042 0.00001 2.53 1.69 0.196 0.1960 1.69
30 14137 0.0141 0.00002 8.55 2.54 0.226 0.0300 2.54 0.22
40 33510 0.0335 0.00004 20.26 3.38 0.514 0.2880 3.38
50 65450 0.0654 0.00009 39.57 4.23 1.816 1.3020 4.23
60 113097 0.1131 0.00015 68.37 5.07 5.702 3.8860 5.07
70 179594 0.1796 0.00024 108.57 5.92 21.348 15.6460 5.92
90 381704 0.3817 0.00051 230.76 7.61 49.812 28.4640 7.61
110 696910 0.6969 0.00093 421.31 9.30 70.509 20.6970 9.30
130 1150347 1.1503 0.00153 695.44 10.99 82.023 11.5140 10.99 75.27
150 1767146 1.7671 0.00235 1068.32 12.68 88.012 5.9890 12.68
180 3053628 3.0536 0.00406 1846.06 15.22 91.032 3.0200 15.22
210 4849048 4.8490 0.00645 2931.47 17.76 92.468 1.4360 17.76
240 7238229 7.2382 0.00963 4375.84 20.29 94.091 1.6230 20.29
270 10305995 10.3060 0.01371 6230.44 22.83 94.689 0.5980 22.83
300 14137167 14.1372 0.01880 8546.56 25.37 96.288 1.5990 25.37
350 22449298 22.4493 0.02986 13571.62 29.59 97.011 0.7230 29.59
400 33510322 33.5103 0.04457 20258.51 33.82 98.340 1.3290 33.82
450 47712938 47.7129 0.06346 28844.64 38.05 99.071 0.7310 38.05
500 65449847 65.4498 0.08705 39567.41 42.28 99.071 0.0000 42.28
600 113097336 113.0973 0.15042 68372.48 50.73 100.000 0.9290 50.73
*EPRI Data - Test Cell, Drift Efficiency = 0.0003%
2)
Circulating Water Rate:3,600 gpm (Input Value)
Drift Rate:0.0005 %(Input Value)
Hours per year operation:8760 hr/yr (Input Value)
Total PM =0.012 lb/hr
(On annual basis =)0.052 tpy
3)Multiply Total PM by PM10 fraction to obtain PM10 emissions:
0.012 x 0.7527 =0.009 lb/hr PM10
or,0.04 tpy
4)Multiply Total PM by PM2.5 fraction to obtain PM2.5 emissions:
0.012 x 0.0022 =0.000027 lb/hr PM2.5
or,0.00012 tpy
Reference: Joel Reisman et al, 2002. Calculating Realistic PM10 Emissions from Cooling Towers. Environmental Progress, Volume 21, Issue 2,
pages 127–130, July 2002
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