DAQ-2024-011079

DAQE-AN161210003-24

{{$d1 }}

Laura Pritchard
Crusoe Energy Systems, Inc.
255 Fillmore Street
Denver, CO 80206
[e-mail]

Dear Ms. Pritchard:

Re: Approval Order: Removal of Permitted Equipment in Approval Order DAQE-AN161210002-23
Under UAC Rule R307-401-12
Project Number: N161210003

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on August
22, 2024. Crusoe Energy Systems, Inc. must comply with the requirements of this AO, all applicable state
requirements (R307), and Federal Standards.

The project engineer for this action is Christine Bodell, who can be contacted at [phone] or
[e-mail]. Future correspondence on this AO should include the engineer's name as well as the
DAQE number shown on the upper right-hand corner of this letter.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:CB:jg

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

September 18, 2024

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

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

APPROVAL ORDER
DAQE-AN161210003-24
Removal of Permitted Equipment in Approval Order
DAQE-AN161210002-23 Under UAC Rule R307-401-12

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

Issued to
Crusoe Energy Systems, Inc. - Duchesne Data Center Power Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

September 18, 2024
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 9
ACRONYMS ............................................................................................................................... 10

DAQE-AN161210003-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Crusoe Energy Systems, Inc. Crusoe Energy Systems, Inc. - Duchesne Data Center Power Station

Mailing Address Physical Address
255 Fillmore Street 1 Mile North East of Upalco
Denver, CO 80206 Duchesne County, UT

Source Contact UTM Coordinates
Name: Laura Pritchard 567,859 m Easting
Phone: [phone],460,140 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 7376 (Computer Facilities Management Services)

SOURCE INFORMATION
General Description
Crusoe Energy Systems, Inc. (Crusoe) owns and operates a data center power station in Duchesne
County. The data center power station contains two (2) compressor engines, ten (10) generator engines,
and one (1) turbine; all the equipment is fueled by gas that would otherwise be flared. The gas comes
from the adjacent XCL facility to the north and other nearby locations. The generators and turbine use the
gas as fuel to generate electricity for small data centers that are also located onsite. Two (2) diesel-fuel
emergency engine generators are on site to power the data centers should the compressor engines,
generator engines, and turbine go down or if there is a loss of utility electrical power.

NSR Classification
Administrative Amendment

Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
DAQE-AN161210003-24
Page 4

NSPS (Part 60), KKKK: Standards of Performance for Stationary Combustion Turbines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
Title V (Part 70) Major Source

Project Description
The Crusoe Duchesne Data Center Power Station Approval Order was issued on February 13, 2023.
Condition I.8 of the 2023 AO requires Crusoe to submit documentation of the status of construction
within 18 months of the AO issuance date. On August 12, 2024, Crusoe submitted documentation
indicating that the two (2) ethylene glycol dehydrators (Equipment ID# II.A.6), two (2) boilers
(Equipment ID# II.A.7), and the three (3) pressurized storage tanks (Equipment ID# II.A.8) had not been
constructed or installed. On August 21, 2024, Crusoe confirmed that it would not be installing the
equipment in the near future.

Therefore, the Approval Order is being updated to remove the non-installed equipment and update the
resulting potential-to-emit (PTE). This project meets the requirements of UAC R307-401-12 Reduction in
Air Pollutants and does not require a public comment period.

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 -651 182702.00
Carbon Monoxide -0.40 111.02
Nitrogen Oxides -0.48 96.11
Particulate Matter - PM10 -0.04 7.13
Particulate Matter - PM2.5 -0.04 7.13
Sulfur Dioxide -0.01 4.87
Volatile Organic Compounds -8.82 27.79

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 4240
Acrolein (CAS #107028) 0 3960
Benzene (Including Benzene From Gasoline) (CAS #71432) -880 2080
Ethyl Benzene (CAS #100414) -40 60
Formaldehyde (CAS #50000) 0 1340
Generic HAPs (CAS #GHAPS) -20 2300
Methanol (CAS #67561) 0 4600
Toluene (CAS #108883) -140 920
Xylenes (Isomers And Mixture) (CAS #1330207) -40 340
Change (TPY) Total (TPY)
Total HAPs -0.56 9.92

DAQE-AN161210003-24
Page 5

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]
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 Duchesne Data Center Power Station
II.A.2 Two (2) Compressor Engines

Rating: 530 HP, each Fuel: Natural Gas
Control: Non-selective catalytic reduction (NSCR)
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

DAQE-AN161210003-24
Page 6

II.A.3 Ten (10) Generator Engines Rating: 2,500 HP, each Fuel: Natural Gas Control: Non-selective catalytic reduction (NSCR) NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ
II.A.4 Two (2) Emergency Engine Generator Sets Rating: 2,944 HP (2,000 kW), each
Fuel: Diesel Control: Tier 4 Final (4f)
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.5 One (1) Turbine Rating: 13,364 kW (133.1 MMBtu/hr) Fuel: Natural Gas Control: SoLoNOx (low NOx burners) NSPS Applicability: 40 CFR 60 Subpart KKKK

SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Natural Gas-Fired Engine and Turbine Requirements
II.B.1.a The owner/operator shall not allow visible emissions from the natural gas-fired engines and turbine to exceed 10% opacity. [R307-401-8]
II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]
II.B.1.b The owner/operator shall use only natural gas as fuel for the 13,364 kW turbine, the 530 HP engines, and the 2,500 HP engines. [R307-401-8]
II.B.1.c The owner/operator shall equip all natural gas-fired engines with a non-selective catalytic
reduction (NSCR) device to control emissions. [R307-401-8]

DAQE-AN161210003-24
Page 7

II.B.2 Stack Test Conditions II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from each of
the indicated sources: Source Pollutant (g/bhp-hr) (lb/hr)
530 HP Compressor Engines NOx 0.15 0.18 CO 0.3 0.35 VOC 0.02 0.02
2,500 HP Generator Engines NOx 0.15 0.83 CO 0.3 1.65
VOC 0.03 0.17 13,634 kW Turbine NOx 0.33 13.33
CO 0.20 8.11 VOC 0.12 4.65

[R307-401-8]
II.B.2.a.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained in this AO. [R307-165-2, R307-401-8]
II.B.2.a.2 Initial Test The owner/operator shall conduct an initial stack test on the emission unit within 180 days after
startup of the emission unit. [R307-165-2]

II.B.2.a.3 Test Frequency To demonstrate compliance with the NOx limits, the owner/operator shall conduct stack testing to verify the NOx emissions. The owner/operator shall conduct a stack test on each emission unit within one (1) year after the date of the most recent stack test of each emission unit. Upon demonstration through at least three (3) annual tests that the NOx limits are not being exceeded, the owner/operator may request approval to conduct stack testing less frequently than annually. To demonstrate compliance with the CO and VOC limits, the owner/operator shall conduct a stack test on each emission unit within three (3) years after the date of the most recent stack test of the emission unit. The Director may require the owner/operator to perform a stack test at any time. [R307-401-8]
II.B.2.b The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8]

II.B.2.b.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8]
II.B.2.b.2 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and
according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]

DAQE-AN161210003-24
Page 8

II.B.2.b.3 Access The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-401-8]
II.B.2.b.4 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8]
II.B.2.c Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8]
II.B.2.c.1 Standard Conditions
A. Temperature - 68oF (293 K).
B. Pressure - 29.92 in Hg (101.3 kPa).

C. Averaging Time - As specified in the applicable test method.
[40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]

II.B.2.c.2 NOx 40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director. [R307-401-8]
II.B.2.c.4 CO 40 CFR 60, Appendix A, Method 10, or other EPA-approved testing method as acceptable to the Director. [R307-401-8]
II.B.3 Diesel-Fired Emergency Engine Generator Set Requirements
II.B.3.a The owner/operator shall not allow visible emissions from the diesel-fired emergency engines to exceed 20% opacity. [R307-401-8]
II.B.3.b The owner/operator shall not operate each 2,944 HP (2,000 kW) emergency generator engine on
site for more than 100 hours per calendar year for maintenance checks and readiness testing. Each 2,944 HP (2,000 kW) emergency generator engine on site may be operated for up to 50
hours per calendar year in non-emergency situations. Any operation in non-emergency situations
shall be counted as part of the 100 hours per calendar year for maintenance and testing. There is
no time limit on the use of the engines during emergencies.
[40 CFR 63 Subpart ZZZZ, R307-401-8]

DAQE-AN161210003-24
Page 9

II.B.3.b.1 To determine compliance with the annual operation limitation, records documenting the operation of each emergency engine shall be kept in a log and shall include the following: A. The date the emergency engine was used. B. The duration of operation in hours. C. The reason for the emergency engine usage. [40 CFR 63 Subpart ZZZZ, R307-401-8]
II.B.3.c To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]
II.B.3.d The owner/operator shall install a 2,944 HP (2,000 kW) emergency engine that is certified to meet a controlled NOx emission rate of no greater than 0.50 g/hp-hr. [R307-401-8]
II.B.3.d.1 To demonstrate compliance with the above condition, the owner/operator shall either:
A. Own/operate a stationary internal combustion engine which has obtained Tier 4
certification as defined in 40 CFR 1039.801; or
B. Conduct an initial performance test according to 40 CFR Part 1039; or

C. Maintain the manufacturer's emissions guarantee for the installed engine model.
[R307-401-8]

II.B.3.d.2 For each 2,944 HP (2,000 kW) engine generator on site, the owner/operator shall maintain records of engine certification, the initial performance test, or the manufacturer's emissions guarantee. [R307-401-8] II.B.3.e The owner/operator shall only use diesel fuel (e.g., fuel oil #1, #2, or diesel fuel oil additives) as
fuel in the stationary diesel engine. [R307-401-8]

II.B.3.f The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur diesel (ULSD) as found in 40 CFR 1090.305. [R307-401-8]
II.B.3.f.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]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:
Supersedes AO DAQE-AN161210002-23 dated February 13, 2023 Incorporates Notice of Construction dated August 12, 2024 Is Derived From NOI dated August 22, 2024
DAQE-AN161210003-24
Page 10

ACRONYMS

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

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

DAQE-

RN161210003
September 16, 2024

Laura Pritchard
Crusoe Energy Systems, Inc.
255 Fillmore Street
Denver, CO 80206
[e-mail]

Dear Laura Pritchard,

Re: Engineer Review:
Removal of Permitted Equipment in Approval Order DAQE-AN161210002-23 Under UAC Rule
R307-401-12
Project Number: N161210003

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. Crusoe
Energy Systems, Inc. should complete this review within 10 business days of receipt.

Crusoe Energy Systems, Inc. should contact Christine Bodell at [phone] if there are questions or
concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email
Christine Bodell at [e-mail] the signed cover letter. Upon receipt of the signed cover letter,
the DAQ will prepare an Approval Order (AO) for signature by the DAQ Director.

If Crusoe Energy Systems, Inc. does not respond to this letter within 10 business days, the project will
move forward without source concurrence. If Crusoe Energy Systems, 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
Lieutenant Governor

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION

Project Number N161210003
Owner Name Crusoe Energy Systems, Inc.
Mailing Address 255 Fillmore Street
Denver, CO, 80206

Source Name Crusoe Energy Systems, Inc.- Duchesne Data Center Power
Station
Source Location 1 Mile North East of Upalco
Duchesne County, UT

UTM Projection 567,859 m Easting, 4,460,140 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 7376 (Computer Facilities Management Services)

Source Contact Laura Pritchard
Phone Number [phone]
Email [e-mail]

Billing Contact Laura Pritchard
Phone Number [phone]
Email [e-mail]

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

Notice of Intent (NOI) Submitted August 22, 2024
Date of Accepted Application August 22, 2024

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 2
SOURCE DESCRIPTION

General Description
Crusoe Energy Systems, Inc (Crusoe) owns and operates a data center power station in Duchesne
County. The data center power station contains two (2) compressor engines, ten (10) generator
engines, and one (1) turbine; all the equipment is fueled by gas that would otherwise be flared.
The gas comes from the adjacent XCL Facility to the north and other nearby locations. The
generators and turbine use the gas as fuel to generate electricity for small data centers that are
also located onsite. Two (2) diesel-fuel emergency engine generators are on site to power the data
centers should the compressor engines, generator engines, and turbine go down or if there is a
loss of utility electrical power.

NSR Classification:
10 Year Review

Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), KKKK: Standards of Performance for Stationary Combustion Turbines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
Title V (Part 70) Major Source

Project Proposal
Removal of Permitted Equipment in Approval Order DAQE-AN161210002-23 Under UAC Rule
R307-401-12

Project Description
The Crusoe Duchesne Data Center Power Station Approval Order was issued on February 13,
2023. Condition I.8 of the 2023 AO requires Crusoe to submit documentation of the status of
construction within 18 months of the AO issuance date. On August 12, 2024, Crusoe submitted
documentation indicating that the two (2) ethylene glycol dehydrators (Equipment ID# II.A.6),
two (2) boilers (Equipment ID# II.A.7), and the three (3) pressurized storage tanks (Equipment
ID# II.A.8) had not been constructed or installed. On August 21, 2024, Crusoe confirmed that it
would not be installing the equipment in the near future.

Therefore, the Approval Order is being updated to remove the non-installed equipment and
update the resulting potential-to-emit (PTE). This project meets the requirements of UAC R307-
401-12 Reduction in Air Pollutants and does not require a public comment period.

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 3
EMISSION IMPACT ANALYSIS
This is an administrative amendment under R307-401-12. No actual emissions are increasing at this time.
Therefore, modeling is not required. [Last updated September 4, 2024]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 4
SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent -651 182702.00
Carbon Monoxide -0.40 111.02
Nitrogen Oxides -0.48 96.11
Particulate Matter - PM10 -0.04 7.13
Particulate Matter - PM2.5 -0.04 7.13
Sulfur Dioxide -0.01 4.87
Volatile Organic Compounds -8.82 27.79

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 4240
Acrolein (CAS #107028) 0 3960
Benzene (Including Benzene From Gasoline) (CAS #71432) -880 2080
Ethyl Benzene (CAS #100414) -40 60
Formaldehyde (CAS #50000) 0 1340
Generic HAPs (CAS #GHAPS) -20 2300
Methanol (CAS #67561) 0 4600
Toluene (CAS #108883) -140 920
Xylenes (Isomers And Mixture) (CAS #1330207) -40 340
Change (TPY) Total (TPY)
Total HAPs -0.56 9.92

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

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 5
Review of BACT for New/Modified Emission Units

1. BACT review regarding Administrative Amendment
This is an administrative amendment under R307-401-12. No actual emissions are increasing at
this time. Therefore, a BACT analysis is not required. [Last updated September 4, 2024]

SECTION I: GENERAL PROVISIONS

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

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

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

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

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of 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 N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 6
SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

II.A THE APPROVED EQUIPMENT

II.A.1 Duchesne Data Center Power Station

II.A.2 Two (2) Compressor Engines

Rating: 530 HP, each
Fuel: Natural Gas
Control: Non-selective catalytic reduction (NSCR)

NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

II.A.3 Ten (10) Generator Engines

Rating: 2,500 HP, each
Fuel: Natural Gas
Control: Non-selective catalytic reduction (NSCR)

NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

II.A.4 Two (2) Emergency Engine Generator Sets

Rating: 2,944 HP (2,000 kW), each
Fuel: Diesel
Control: Tier 4 Final (4f)

NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ

II.A.5 One (1) Turbine

Rating: 13,364 kW (133.1 MMBtu/hr)
Fuel: Natural Gas
Control: SoLoNOx (low NOx burners)

NSPS Applicability: 40 CFR 60 Subpart KKKK

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

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 7
II.B.1 Natural Gas-Fired Engine and Turbine Requirements
II.B.1.a The owner/operator shall not allow visible emissions from the natural gas-fired engines and
turbine to exceed 10% opacity. [R307-401-8]

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

II.B.1.b The owner/operator shall use only natural gas as fuel for the 13,364 kW turbine, the 530 HP
engines, and the 2,500 HP engines. [R307-401-8]

II.B.1.c The owner/operator shall equip all natural-gas fired engines with a non-selective catalytic
reduction (NSCR) device to control emissions. [R307-401-8]

II.B.2 Stack Test Conditions
II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from each
of the indicated sources:
Source Pollutant (g/bhp-hr) (lb/hr)
530 HP Compressor Engines NOx 0.15 0.18
CO 0.3 0.35
VOC 0.02 0.02

2,500 HP Generator Engines NOx 0.15 0.83
CO 0.3 1.65
VOC 0.03 0.17

13,634 kW Turbine NOx 0.33 13.33
CO 0.20 8.11
VOC 0.12 4.65

[R307-401-8]

II.B.2.a.1 Compliance Demonstration
To demonstrate compliance with the emission limitations above, the owner/operator shall
perform stack testing on the emissions unit according to the stack testing conditions contained
in this AO. [R307-165-2, R307-401-8]

II.B.2.a.2 Initial Test
The owner/operator shall conduct an initial stack test on the emission unit within 180 days
after startup of the emission unit. [R307-165-2]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 8
II.B.2.a.3 Test Frequency
To demonstrate compliance with the NOx limits, the owner/operator shall conduct stack
testing to verify the NOx emissions. The owner/operator shall conduct a stack test on each
emission unit within one (1) year after the date of the most recent stack test of each emission
unit. Upon demonstration through at least three (3) annual tests that the NOx limits are not
being exceeded, the owner/operator may request approval to conduct stack testing less
frequently than annually.

To demonstrate compliance with the CO and VOC limits, the owner/operator shall conduct a
stack test on each emission unit within three (3) years after the date of the most recent stack
test of the emission unit.

The Director may require the owner/ operator to perform a stack test at any time. [R307-401-
8]

II.B.2.b The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.2.b.1 Notification
At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test
protocol to the Director. The source test protocol shall include the items contained in R307-
165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-
165-3, R307-401-8]

II.B.2.b.2 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and
according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]

II.B.2.b.3 Access
The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or
Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-
401-8]

II.B.2.b.4 Reporting
No later than 60 days after completing a stack test, the owner/operator shall submit a written
report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8]

II.B.2.c Test Methods
When performing stack testing, the owner/operator shall use the appropriate EPA-approved
test methods as acceptable to the Director. Acceptable test methods for pollutants are listed
below. [R307-401-8]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 9
II.B.2.c.1 Standard Conditions

A. Temperature - 68oF (293 K)

B. Pressure - 29.92 in Hg (101.3 kPa)

C. Averaging Time - As specified in the applicable test method

[40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]

II.B.2.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

II.B.2.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director. [R307-401-
8]

II.B.2.c.4 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to
the Director. [R307-401-8]

II.B.3 Diesel-Fired Emergency Engine Generator Set Requirements
II.B.3.a The owner/operator shall not allow visible emissions from the diesel-fired emergency engines
to exceed 20% opacity. [R307-401-8]

II.B.3.b The owner/operator shall not operate each 2,944 HP (2,000 kW) emergency generator engine
on site for more than 100 hours per calendar year for maintenance checks and readiness
testing. Each 2,944 HP (2,000 kW) emergency generator engine on site may be operated for
up to 50 hours per calendrer year in non-emergency situations. Any operation in non-
emergency situations shall be counted as part of the 100 hours per calendar year for
maintenance and testing. There is no time limit on the use of the engines during emergencies.
[40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.3.b.1 To determine compliance with the annual operation limitation, records documenting the
operation of each emergency engine shall be kept in a log and shall include the following:

A. The date the emergency engine was used

B. The duration of operation in hours

C. The reason for the emergency engine usage

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

II.B.3.c To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 10
II.B.3.d The owner/operator shall install a 2,944 HP (2,000 kW) emergency engine that is certified to
meet a controlled NOx emission rate of no greater than 0.50 g/hp-hr. [R307-401-8]

II.B.3.d.1 To demonstrate compliance with the above condition, the owner/operator shall either:

A. Own/operate a stationary internal combustion engine which has obtained Tier 4
certification as defined in 40 CFR 1039.801; or

B. Conduct an initial performance test according to 40 CFR part 1039; or

C. Maintain the manufacturer's emissions guarantee for the installed engine model.

[R307-401-8]

II.B.3.d.2 For each 2,944 HP (2,000 kW) engine generator on site, the owner/operator shall maintain
records of engine certification, the initial performance test, or the manufacturer's emissions
guarantee. [R307-401-8]

II.B.3.e The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives)
as fuel in the stationary diesel engine. [R307-401-8]

II.B.3.f The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur
diesel (ULSD) as found in 40 CFR 1090.305. [R307-401-8]

II.B.3.f.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]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 11
PERMIT HISTORY

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

Supersedes AO DAQE-AN161210002-23 dated February 13, 2023
Is Derived From Notice of Construction dated August 12, 2024

REVIEWER COMMENTS

1. Comment regarding Administrative Amendment:
The removed equipment includes two (2) ethylene glycol (EG) dehydrators, two (2) boilers, and the
three (3) pressurized storage tanks.

Based on the Crusoe 2023 NOI, the total emissions from both EG dehydrators were estimated to be
5.72 tpy of VOCs, 0.17 tpy of HAPs, and 79.98 tpy of CO2e. The total emissions from both boilers
were estimate to be 0.48 tpy of NOx, 0.40 tpy of CO, 0.03 tpy of VOCs, 0.01 tpy of SO2, 0.04 tpy of
PM10, 0.04 tpy of PM2.5, 0.01 tpy of HAPs, and 565.60 tpy of CO2e. The three NGL storage tanks
were pressurized and therefore were expected to emit negligible (<0.01 tpy) levels of air pollutants.
However, VOC emissions were expected to be released during NGL storage tank-truck loadout
transfer operations. Emissions from this were estimated to be 2.67 tpy of VOCs, 0.37 tpy of HAPs,
and 5.01 tpy of CO2e.

The changes result in the following reduction in PTE: 0.48 tpy of NOx, 0.40 tpy of CO, 8.42 tpy of
VOCs, 0.01 tpy of SO2, 0.04 tpy of PM10, 0.04 tpy of PM2.5, 0.55 tpy of HAPs, and 650.59 tpy of
CO2e. Of the 0.55 tpy HAPs reduction, 0.44 tpy is benzene, 0.07 tpy is toluene, 0.02 tpy is
ethylbenzene, 0.02 tpy are xylenes, and 0.01 tpy are generic HAPs. The values may vary slightly due
to rounding.

The site-wide PTEs have been adjusted accordingly.

Additionally, AO DAQE-AN161210002-23 contains Monitoring Requirements of Fugitive
Emissions (Leak Detection and Repair) requirements (Condition Section II.B.4). A leak detection
and repair (LDAR) program was determined to be BACT when evaluating controls for emissions
from the EG dehydrators and boilers. Because the EG dehydrators and boilers were not installed and
NSPS Subpart OOOOa is no longer applicable to the facility, the BACT-determined LDAR program
no longer applies. As such, the conditions have been removed.

[Last updated September 9, 2024]

2. Comment regarding NSPS Federal Subpart Applicability:
40 CFR 60 NSPS Subpart IIII (Standards of Performance for Stationary Compression Ignition
Internal Combustion Engines) applies to owners and operators of stationary CI ICE that commence
construction after July 11, 2005, where the stationary CI ICE is manufactured after April 1, 2006.
The production date of the two (2) 2,000 kW generators is post April 1, 2006. Therefore, NSPS
Subpart IIII applies.

40 CFR 60 NSPS Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines) applies to engines that were ordered after June 12, 2006 and manufactured on
or after July 1, 2007 for engines with maximum power greater than or equal to 500 hp

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 12
(§60.4230(a)(4)(i)). Thus, NSPS Subpart JJJJ applies to the Crusoe Facility as the two (2) 530 hp
compressor engines and ten (10) 2,500 hp generator engines were ordered after June 12, 2006 and
manufactured after July 1, 2007.

40 CFR 60 Subpart KKKK (Standards of Performance for Stationary Combustion Turbines) applies
to owners and operators of all stationary combustion turbines with a heat input at peak load equal to
or greater than 10 million BTU per hour based on the higher heating value of the fuel, which
commenced construction, modification, or reconstruction after February 18, 2005. Therefore, NSPS
Subpart KKKK applies to the Crusoe facility as the turbine has a heat input rating of 10 million
British thermal units (Btu) per hour and will be installed after February 8, 2005.

40 CFR 60 Subpart OOOOa (Standards of Performance for Crude Oil and Natural Gas Facilities for
which Construction, Modification or Reconstruction Commenced After September 18, 2015) applies
to owners and operators of onshore facilities that are located within the Crude Oil and Natural Gas
Production source category that commence construction, modification, or reconstruction after
September 18, 2015. Initially, a portion of the Crusoe facility was considered an onshore natural gas
processing plant as defined by Subpart OOOOa. Subject equipment included the EG dehydrators,
reboilers, and bullet tanks. Crusoe will not be installing the applicable equipment. Therefore, this
Subpart no longer applies.
[Last updated September 4, 2024]

3. Comment regarding MACT Federal Subpart Applicability:
40 CFR 63 Subpart HH (National Emission Standards for Hazardous Air Pollutants from Oil and
Natural Gas Production Facilities) applies to oil and natural gas production facilities that are a major
or area source of HAP emissions, and that process, upgrade, or store hydrocarbon liquids or natural
gas prior to the transmission and storage source category (§63.760(a)). Per the definitions in
§63.761, the Crusoe Facility was previously considered a "production field facility", as it is before
custody transfer (before a gas processing plant). However, Crusoe is no longer installing the EG
dehydrators or bullet tanks. Therefore, this Subpart no longer applies to the facility.

40 CFR 63 Subpart ZZZZ (National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines) is applicable to owners/operators of
stationary RICE at a major or area sources of HAP emissions. MACT Subpart ZZZZ applies to the
Crusoe Facility as the compressor engines and generators are new RICE. The compressor engines
and generator engines will meet Subpart ZZZZ by meeting 40 CFR Part 60, Subpart JJJJ as the
Crusoe Facility is an area source of HAP emissions. Additionally, Subpart ZZZZ applies to the
Crusoe Facility as the diesel generators are new CI ICE. The diesel generators will meet Subpart
ZZZZ by meeting 40 CFR Part 60, Subpart IIII as the Crusoe Facility is an area source of HAP
emissions. [Last updated September 4, 2024]

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

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

This facility is not a Title IV source, but is a major source for CO. The facility is not subject to 40

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 13
CFR 61 (NESHAP) regulations. It is subject to 40 CFR 60 (NSPS) Subparts A, IIII, JJJJ, and KKKK
and to 40 CFR 63 (MACT) Subparts A and ZZZZ. NSPS Subparts IIII, and JJJJ and MACT Subpart
ZZZZ each exempt sources from the obligation to obtain a permit under 40 CFR Part 70, provided
that the source is not required to obtain the permit for any other reason. However, NSPS Subpart
KKKK does not include this exemption. Therefore, Title V applies to this facility as a major source.
[Last updated September 4, 2024]

Engineer Review N161210003: Crusoe Energy Systems, Inc.- Duchesne Data Center Power Station
September 16, 2024
Page 14
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

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
RN161210003
September 16, 2024
Laura Pritchard
Crusoe Energy Systems, Inc.
255 Fillmore Street
Denver, CO 80206
[e-mail]
Dear Laura Pritchard,
Re: Engineer Review:
Removal of Permitted Equipment in Approval Order DAQE-AN161210002-23 Under UAC Rule
R307-401-12
Project Number: N161210003
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. Crusoe
Energy Systems, Inc. should complete this review within 10 business days of receipt.
Crusoe Energy Systems, Inc. should contact Christine Bodell at [phone] if there are questions or
concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email
Christine Bodell at [e-mail] the signed cover letter. Upon receipt of the signed cover letter,
the DAQ will prepare an Approval Order (AO) for signature by the DAQ Director.
If Crusoe Energy Systems, Inc. does not respond to this letter within 10 business days, the project will
move forward without source concurrence. If Crusoe Energy Systems, 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)
9/16/2024
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW
SOURCE INFORMATION
Project Number N161210003
Owner Name Crusoe Energy Systems, Inc.
Mailing Address 255 Fillmore Street
Denver, CO, 80206
Source Name Crusoe Energy Systems, Inc.- Duchesne Data Center Power
Station
Source Location 1 Mile North East of Upalco
Duchesne County, UT
UTM Projection 567,859 m Easting, 4,460,140 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 7376 (Computer Facilities Management Services)
Source Contact Laura Pritchard
Phone Number [phone]
Email [e-mail]
Billing Contact Laura Pritchard
Phone Number [phone]
Email [e-mail]
Project Engineer Christine Bodell, Engineer
Phone Number [phone]
Email [e-mail]
Notice of Intent (NOI) Submitted August 22, 2024
Date of Accepted Application August 22, 2024
SOURCE DESCRIPTION
General Description
Crusoe Energy Systems, Inc (Crusoe) owns and operates a data center power station in Duchesne County.
The data center power station contains two (2) compressor engines, ten (10) generator engines, and one
(1) turbine; all the equipment is fueled by gas that would otherwise be flared. The gas comes from the
adjacent XCL Facility to the north and other nearby locations. The generators and turbine use the gas as
fuel to generate electricity for small data centers that are also located onsite. Two (2) diesel-fuel
emergency engine generators are on site to power the data centers should the compressor engines,
generator engines, and turbine go down or if there is a loss of utility electrical power.
NSR Classification:
10 Year Review
Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: A
Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), KKKK: Standards of Performance for Stationary Combustion Turbines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
Title V (Part 70) Major Source
Project Proposal
Removal of Permitted Equipment in Approval Order DAQE-AN161210002-23 Under UAC Rule
R307-401-12
Project Description
The Crusoe Duchesne Data Center Power Station Approval Order was issued on February 13, 2023.
Condition I.8 of the 2023 AO requires Crusoe to submit documentation of the status of construction
within 18 months of the AO issuance date. On August 12, 2024, Crusoe submitted documentation
indicating that the two (2) ethylene glycol dehydrators (Equipment ID# II.A.6), two (2) boilers
(Equipment ID# II.A.7), and the three (3) pressurized storage tanks (Equipment ID# II.A.8) had not been
constructed or installed. On August 21, 2024, Crusoe confirmed that it would not be installing the
equipment in the near future.
Therefore, the Approval Order is being updated to remove the non-installed equipment and update the
resulting potential-to-emit (PTE). This project meets the requirements of UAC R307-401-12 Reduction in
Air Pollutants and does not require a public comment period.
EMISSION IMPACT ANALYSIS
This is an administrative amendment under R307-401-12. No actual emissions are increasing at this
time. Therefore, modeling is not required. [Last updated September 4, 2024]
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 -651 182702.00
Carbon Monoxide -0.40 111.02
Nitrogen Oxides -0.48 96.11
Particulate Matter - PM10 -0.04 7.13
Particulate Matter - PM2.5 -0.04 7.13
Sulfur Dioxide -0.01 4.87
Volatile Organic Compounds -8.82 27.79
Hazardous Air Pollutant Change (lbs/yr)Total (lbs/yr)
Acetaldehyde (CAS #75070)0 4240
Acrolein (CAS #107028)0 3960
Benzene (Including Benzene From Gasoline) (CAS #71432)-880 2080
Ethyl Benzene (CAS #100414)-40 60
Formaldehyde (CAS #50000)0 1340
Generic HAPs (CAS #GHAPS)-20 2300
Methanol (CAS #67561)0 4600
Toluene (CAS #108883)-140 920
Xylenes (Isomers And Mixture) (CAS #1330207)-40 340
Change (TPY)Total (TPY)
Total HAPs -0.56 9.92
Note: Change in emissions indicates the difference between previous AO and proposed modification.
Review of BACT for New/Modified Emission Units
1.BACT review regarding Administrative Amendment
This is an administrative amendment under R307-401-12. No actual emissions are increasing
at this time. Therefore, a BACT analysis is not required. [Last updated September 4, 2024]
SECTION I: GENERAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.
(New or Modified conditions are indicated as “New” in the Outline Label):
I.1 All definitions, terms, abbreviations, and references used in this AO conform to those
used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these
AO conditions refer to those rules. [R307-101]
I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]
I.4 All records referenced in this AO or in other applicable rules, which are required to be
kept by the owner/operator, shall be made available to the Director or Director's
representative upon request, and the records shall include the two-year period prior to
the date of the request. Unless otherwise specified in this AO or in other applicable
state and federal rules, records shall be kept for a minimum of 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]
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 Duchesne Data Center Power Station
II.A.2 Two (2) Compressor Engines

Rating: 530 HP, each
Fuel: Natural Gas
Control: Non-selective catalytic reduction (NSCR)
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ
II.A.3 Ten (10) Generator Engines

Rating: 2,500 HP, each
Fuel: Natural Gas
Control: Non-selective catalytic reduction (NSCR)

NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ
II.A.4 Two (2) Emergency Engine Generator Sets

Rating: 2,944 HP (2,000 kW), each
Fuel: Diesel
Control: Tier 4 Final (4f)
NSPS/MACT Applicability: 40 CFR 60 Subpart IIII, 40 CFR 63 Subpart ZZZZ
II.A.5 One (1) Turbine

Rating: 13,364 kW (133.1 MMBtu/hr)
Fuel: Natural Gas
Control: SoLoNOx (low NOx burners)

NSPS Applicability: 40 CFR 60 Subpart KKKK
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 Natural Gas-Fired Engine and Turbine Requirements
II.B.1.a The owner/operator shall not allow visible emissions from the natural gas-fired engines
and turbine to exceed 10% opacity. [R307-401-8]
II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in
accordance with 40 CFR 60, Method 9. [R307-401-8]
II.B.1.b The owner/operator shall use only natural gas as fuel for the 13,364 kW turbine, the 530
HP engines, and the 2,500 HP engines. [R307-401-8]
II.B.1.c The owner/operator shall equip all natural-gas fired engines with a non-selective
catalytic reduction (NSCR) device to control emissions. [R307-401-8]
II.B.2 Stack Test Conditions
II.B.2.a The owner/operator shall not emit more than the following rates and concentrations
from each of the indicated sources:
Source Pollutant (g/bhp-hr)(lb/hr)
530 HP Compressor Engines NOx 0.15 0.18
CO 0.3 0.35
VOC 0.02 0.02
2,500 HP Generator Engines NOx 0.15 0.83
CO 0.3 1.65
VOC 0.03 0.17
13,634 kW Turbine NOx 0.33 13.33
CO 0.20 8.11
VOC 0.12 4.65

[R307-401-8]
II.B.2.a.1 Compliance Demonstration
To demonstrate compliance with the emission limitations above, the owner/operator
shall perform stack testing on the emissions unit according to the stack testing
conditions contained in this AO. [R307-165-2, R307-401-8]
II.B.2.a.2 Initial Test
The owner/operator shall conduct an initial stack test on the emission unit within 180
days after startup of the emission unit. [R307-165-2]
II.B.2.a.3 Test Frequency
To demonstrate compliance with the NOx limits, the owner/operator shall conduct stack
testing to verify the NOx emissions. The owner/operator shall conduct a stack test on
each emission unit within one (1) year after the date of the most recent stack test of each
emission unit. Upon demonstration through at least three (3) annual tests that the NOx
limits are not being exceeded, the owner/operator may request approval to conduct stack
testing less frequently than annually.

To demonstrate compliance with the CO and VOC limits, the owner/operator shall
conduct a stack test on each emission unit within three (3) years after the date of the
most recent stack test of the emission unit.

The Director may require the owner/ operator to perform a stack test at any time.
[R307-401-8]
II.B.2.b The owner/operator shall conduct any stack testing required by this AO according
to the following conditions. [R307-401-8]
II.B.2.b.1 Notification
At least 30 days prior to conducting a stack test, the owner/operator shall submit a
source test protocol to the Director. The source test protocol shall include the items
contained in R307-165-3. If directed by the Director, the owner/operator shall attend a
pretest conference. [R307-165-3, R307-401-8]
II.B.2.b.2 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol
and according to the test conditions contained in R307-165-4. [R307-165-4,
R307-401-8]
II.B.2.b.3 Access
The owner/operator shall provide Occupational Safety and Health Administration
(OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the
test location. [R307-401-8]
II.B.2.b.4 Reporting
No later than 60 days after completing a stack test, the owner/operator shall submit a
written report of the results from the stack testing to the Director. The report shall
include validated results and supporting information. [R307-165-5, R307-401-8]
II.B.2.c Test Methods
When performing stack testing, the owner/operator shall use the appropriate EPA-
approved test methods as acceptable to the Director. Acceptable test methods for
pollutants are listed below. [R307-401-8]
II.B.2.c.1 Standard Conditions
A. Temperature - 68oF (293 K)
B. Pressure - 29.92 in Hg (101.3 kPa)
C. Averaging Time - As specified in the applicable test method

[40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]
II.B.2.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method
as acceptable to the Director. [R307-401-8]
II.B.2.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix
A, Method 320; or other EPA-approved testing method as acceptable to the Director.
[R307-401-8]
II.B.2.c.4 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]
II.B.3 Diesel-Fired Emergency Engine Generator Set Requirements
II.B.3.a The owner/operator shall not allow visible emissions from the diesel-fired emergency
engines to exceed 20% opacity. [R307-401-8]
II.B.3.b The owner/operator shall not operate each 2,944 HP (2,000 kW) emergency generator
engine on site for more than 100 hours per calendar year for maintenance checks and
readiness testing. Each 2,944 HP (2,000 kW) emergency generator engine on site may
be operated for up to 50 hours per calendrer year in non-emergency situations. Any
operation in non-emergency situations shall be counted as part of the 100 hours per
calendar year for maintenance and testing. There is no time limit on the use of the
engines during emergencies. [40 CFR 63 Subpart ZZZZ, R307-401-8]
II.B.3.b.1 To determine compliance with the annual operation limitation, records documenting the
operation of each emergency engine shall be kept in a log and shall include the
following:
A. The date the emergency engine was used
B. The duration of operation in hours
C. The reason for the emergency engine usage

[40 CFR 63 Subpart ZZZZ, R307-401-8]
II.B.3.c To determine the duration of operation, the owner/operator shall install a non-resettable
hour meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]
II.B.3.d The owner/operator shall install a 2,944 HP (2,000 kW) emergency engine that is
certified to meet a controlled NOx emission rate of no greater than 0.50 g/hp-hr.
[R307-401-8]
II.B.3.d.1 To demonstrate compliance with the above condition, the owner/operator shall either:

A. Own/operate a stationary internal combustion engine which has obtained Tier 4
certification as defined in 40 CFR 1039.801; or

B. Conduct an initial performance test according to 40 CFR part 1039; or

C. Maintain the manufacturer's emissions guarantee for the installed engine model.

[R307-401-8]
II.B.3.d.2 For each 2,944 HP (2,000 kW) engine generator on site, the owner/operator shall
maintain records of engine certification, the initial performance test, or the
manufacturer's emissions guarantee. [R307-401-8]
II.B.3.e The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil
additives) as fuel in the stationary diesel engine. [R307-401-8]
II.B.3.f The owner/operator shall only combust diesel fuel that meets the definition of ultra-low
sulfur diesel (ULSD) as found in 40 CFR 1090.305. [R307-401-8]
II.B.3.f.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]
PERMIT HISTORY
When issued, the approval order shall supersede (if a modification) or will be based on the following
documents:
Supersedes AO DAQE-AN161210002-23 dated February 13, 2023
Is Derived From Notice of Construction dated August 12, 2024
REVIEWER COMMENTS
1.Comment regarding Administrative Amendment:
The removed equipment includes two (2) ethylene glycol (EG) dehydrators, two (2) boilers,
and the three (3) pressurized storage tanks.
Based on the Crusoe 2023 NOI, the total emissions from both EG dehydrators were estimated
to be 5.72 tpy of VOCs, 0.17 tpy of HAPs, and 79.98 tpy of CO2e. The total emissions from
both boilers were estimate to be 0.48 tpy of NOx, 0.40 tpy of CO, 0.03 tpy of VOCs, 0.01 tpy
of SO2, 0.04 tpy of PM10, 0.04 tpy of PM2.5, 0.01 tpy of HAPs, and 565.60 tpy of CO2e.
The three NGL storage tanks were pressurized and therefore were expected to emit negligible
(<0.01 tpy) levels of air pollutants. However, VOC emissions were expected to be released
during NGL storage tank-truck loadout transfer operations. Emissions from this were
estimated to be 2.67 tpy of VOCs, 0.37 tpy of HAPs, and 5.01 tpy of CO2e.
The changes result in the following reduction in PTE: 0.48 tpy of NOx, 0.40 tpy of CO, 8.42
tpy of VOCs, 0.01 tpy of SO2, 0.04 tpy of PM10, 0.04 tpy of PM2.5, 0.55 tpy of HAPs, and
650.59 tpy of CO2e. Of the 0.55 tpy HAPs reduction, 0.44 tpy is benzene, 0.07 tpy is toluene,
0.02 tpy is ethylbenzene, 0.02 tpy are xylenes, and 0.01 tpy are generic HAPs. The values
may vary slightly due to rounding.
The site-wide PTEs have been adjusted accordingly.
Additionally, AO DAQE-AN161210002-23 contains Monitoring Requirements of Fugitive
Emissions (Leak Detection and Repair) requirements (Condition Section II.B.4). A leak
detection and repair (LDAR) program was determined to be BACT when evaluating controls
for emissions from the EG dehydrators and boilers. Because the EG dehydrators and boilers
were not installed and NSPS Subpart OOOOa is no longer applicable to the facility, the
BACT-determined LDAR program no longer applies. As such, the conditions have been
removed.
[Last updated September 9, 2024]
2.Comment regarding NSPS Federal Subpart Applicability:
40 CFR 60 NSPS Subpart IIII (Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines) applies to owners and operators of stationary CI ICE
that commence construction after July 11, 2005, where the stationary CI ICE is manufactured
after April 1, 2006. The production date of the two (2) 2,000 kW generators is post April 1,
2006. Therefore, NSPS Subpart IIII applies.
40 CFR 60 NSPS Subpart JJJJ (Standards of Performance for Stationary Spark Ignition
Internal Combustion Engines) applies to engines that were ordered after June 12, 2006 and
manufactured on or after July 1, 2007 for engines with maximum power greater than or equal
to 500 hp (§60.4230(a)(4)(i)). Thus, NSPS Subpart JJJJ applies to the Crusoe Facility as the
two (2) 530 hp compressor engines and ten (10) 2,500 hp generator engines were ordered
after June 12, 2006 and manufactured after July 1, 2007.
40 CFR 60 Subpart KKKK (Standards of Performance for Stationary Combustion Turbines)
applies to owners and operators of all stationary combustion turbines with a heat input at peak
load equal to or greater than 10 million BTU per hour based on the higher heating value of
the fuel, which commenced construction, modification, or reconstruction after February 18,
2005. Therefore, NSPS Subpart KKKK applies to the Crusoe facility as the turbine has a heat
input rating of 10 million British thermal units (Btu) per hour and will be installed after
February 8, 2005.
40 CFR 60 Subpart OOOOa (Standards of Performance for Crude Oil and Natural Gas
Facilities for which Construction, Modification or Reconstruction Commenced After
September 18, 2015) applies to owners and operators of onshore facilities that are located
within the Crude Oil and Natural Gas Production source category that commence
construction, modification, or reconstruction after September 18, 2015. Initially, a portion of
the Crusoe facility was considered an onshore natural gas processing plant as defined by
Subpart OOOOa. Subject equipment included the EG dehydrators, reboilers, and bullet tanks.
Crusoe will not be installing the applicable equipment. Therefore, this Subpart no longer
applies.
[Last updated September 4, 2024]
3.Comment regarding MACT Federal Subpart Applicability:
40 CFR 63 Subpart HH (National Emission Standards for Hazardous Air Pollutants from Oil
and Natural Gas Production Facilities) applies to oil and natural gas production facilities that
are a major or area source of HAP emissions, and that process, upgrade, or store hydrocarbon
liquids or natural gas prior to the transmission and storage source category (§63.760(a)). Per
the definitions in §63.761, the Crusoe Facility was previously considered a "production field
facility", as it is before custody transfer (before a gas processing plant). However, Crusoe is
no longer installing the EG dehydrators or bullet tanks. Therefore, this Subpart no longer
applies to the facility.
40 CFR 63 Subpart ZZZZ (National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines) is applicable to owners/operators of
stationary RICE at a major or area sources of HAP emissions. MACT Subpart ZZZZ applies
to the Crusoe Facility as the compressor engines and generators are new RICE. The
compressor engines and generator engines will meet Subpart ZZZZ by meeting 40 CFR Part
60, Subpart JJJJ as the Crusoe Facility is an area source of HAP emissions. Additionally,
Subpart ZZZZ applies to the Crusoe Facility as the diesel generators are new CI ICE. The
diesel generators will meet Subpart ZZZZ by meeting 40 CFR Part 60, Subpart IIII as the
Crusoe Facility is an area source of HAP emissions. [Last updated September 4, 2024]
4.Comment regarding Title V Applicability:
Title V of the 1990 Clean Air Act (Title V) applies to the following:
1. Any major source
2. Any source subject to a standard, limitation, or other requirement under Section 111 of the
Act, Standards of Performance for New Stationary Sources;
3. Any source subject to a standard or other requirement under Section 112 of the Act,
Hazardous Air Pollutants.
4. Any Title IV affected source.
This facility is not a Title IV source, but is a major source for CO. The facility is not subject
to 40 CFR 61 (NESHAP) regulations. It is subject to 40 CFR 60 (NSPS) Subparts A, IIII,
JJJJ, and KKKK and to 40 CFR 63 (MACT) Subparts A and ZZZZ. NSPS Subparts IIII, and
JJJJ and MACT Subpart ZZZZ each exempt sources from the obligation to obtain a permit
under 40 CFR Part 70, provided that the source is not required to obtain the permit for any
other reason. However, NSPS Subpart KKKK does not include this exemption. Therefore,
Title V applies to this facility as a major source.
[Last updated September 4, 2024]
ACRONYMS
The following lists commonly used acronyms and associated translations as they apply to this document:
40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by EPA to classify sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal UDAQ use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)
GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/HR Pounds per hour
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds
7,000 BTU/hp-hrEquipment DetailsRating 5,360 hp = (4000 kw)Table 3.3-1Operational Hours 200 hours/year <600 hpSulfur Content 15 ppm or 0.0015%lb/hp-hr lb/hr Ton/yearCheck EF x S lb/hp-hr lb/hr Ton/year CheckNox - Uncontrolled 0.031 166.16 16.62 0.024 128.64 12.86
Criteria Pollutant
EmissionStandards(g/hp-hr)
Emission Factor(lb/hp-hr)
EmissionRate(lbs/hr)
Total(tons/year)Reference Nox - Controlled 0.013 69.68 6.97NOX0.38 4.49 0.45 CO 6.68E-03 35.80 3.58 5.50E-03 29.48 2.95CO0.10 1.18 0.12 SO2 2.05E-03 10.99 1.10 8.09E-03 1.21E-05 0.07 0.01 Match Used>600 hp to allow for sulfur content of fuelPM100.01 0.12 0.01 PM10 2.20E-03 11.79 1.18 0.0007 3.75 0.38 Table 3.3-1 does not allow for a sulfur content.PM2.5 0.01 0.12 0.01 CO2 1.15E+00 6,164 616 1.16 6,218 622 Match To be more representatvie, Table 3.4-1 was used for all engine sizes.
VOC 0.01 0.12 0.01 Aldehydes 4.63E-04 Not used, included in HAP below.SO2 1.21E-05 0.07 0.01 AP-42 Table 3.4-1 TOC 2.51E-03 13.45 1.35 7.05E-04 3.78 0.38 for engines >600 hp, TOC is 91% VOC & 9% methaneHAP0.06 0.01 See Below VOC 2.51E-03 13.48 1.35 91%6.42E-04 3.44 0.34Methane9%6.35E-05 0.34 0.03 Match
Green House Gas Pollutant
Global Warming Potential
Emission Factor(lb/hp-hr)
EmissionRate(lbs/hr)
Total(tons/year)Reference Exhaust 2.47E-03CO2 (mass basis)1 1.16 6,218 622 Evaporative 0.00Methane (mass basis)25 6.35E-05 0 0 Crankcase 4.41E-05CO2e623Refueling0.00
Hazardous Air Pollutant
EmissionRate(lbs/hr)
Total(tons/year)Reference HAP
Table 3.3-2<600 hp(lb/MMBtu)lb/hp-hr lb/hr Ton/year Check
Table 3.4-3>600 hp(lb/MMBtu)lb/hp-hr lb/hr Ton/year CheckBenzene7.76E-04 2.91E-02 2.91E-03 Benzene 9.33E-04 6.53E-06 3.50E-02 3.50E-03 7.76E-04 5.43E-06 2.91E-02 2.91E-03 MatchToluene2.81E-04 1.05E-02 1.05E-03 Toluene 4.09E-04 2.86E-06 1.53E-02 1.53E-03 2.81E-04 1.97E-06 1.05E-02 1.05E-03 MatchXylenes1.93E-04 7.24E-03 7.24E-04 Xylenes 2.85E-04 2.00E-06 1.07E-02 1.07E-03 1.93E-04 1.35E-06 7.24E-03 7.24E-04 Match1,3-Butadiene 3.91E-05 2.74E-07 1.47E-03 1.47E-04 MatchFormaldehyde7.89E-05 2.96E-03 2.96E-04 Formaldehyde 1.18E-03 8.26E-06 4.43E-02 4.43E-03 7.89E-05 5.52E-07 2.96E-03 2.96E-04 MatchAcetaldehyde2.52E-05 9.46E-04 9.46E-05 Acetaldehyde 7.67E-04 5.37E-06 2.88E-02 2.88E-03 2.52E-05 1.76E-07 9.46E-04 9.46E-05 MatchAcrolein7.88E-06 2.96E-04 2.96E-05 Acrolein 9.25E-05 6.48E-07 3.47E-03 3.47E-04 7.88E-06 5.52E-08 2.96E-04 2.96E-05 MatchNaphthalene1.30E-04 4.88E-03 4.88E-04 Naphthalene 8.48E-05 5.94E-07 3.18E-03 3.18E-04 1.30E-04 9.10E-07 4.88E-03 4.88E-04 MatchAcenaphthylene9.23E-06 3.46E-04 3.46E-05 Acenaphthylene 5.06E-06 3.54E-08 1.90E-04 1.90E-05 9.23E-06 6.46E-08 3.46E-04 3.46E-05 MatchAcenaphthene4.68E-06 1.76E-04 1.76E-05 Acenaphthene 1.42E-06 9.94E-09 5.33E-05 5.33E-06 4.68E-06 3.28E-08 1.76E-04 1.76E-05 MatchFluorene1.28E-05 4.80E-04 4.80E-05 Fluorene 2.92E-05 2.04E-07 1.10E-03 1.10E-04 1.28E-05 8.96E-08 4.80E-04 4.80E-05 MatchPhenanthrene4.08E-05 1.53E-03 1.53E-04 Phenanthrene 2.94E-05 2.06E-07 1.10E-03 1.10E-04 4.08E-05 2.86E-07 1.53E-03 1.53E-04 MatchAnthracene1.23E-06 4.61E-05 4.61E-06 Anthracene 1.87E-06 1.31E-08 7.02E-05 7.02E-06 1.23E-06 8.61E-09 4.61E-05 4.61E-06 MatchFluoranthene4.03E-06 1.51E-04 1.51E-05 Fluoranthene 7.61E-06 5.33E-08 2.86E-04 2.86E-05 4.03E-06 2.82E-08 1.51E-04 1.51E-05 MatchPyrene3.71E-06 1.39E-04 1.39E-05 Pyrene 4.78E-06 3.35E-08 1.79E-04 1.79E-05 3.71E-06 2.60E-08 1.39E-04 1.39E-05 MatchBenz(a)anthracene 6.22E-07 2.33E-05 2.33E-06 Benz(a)anthracene 1.68E-06 1.18E-08 6.30E-05 6.30E-06 6.22E-07 4.35E-09 2.33E-05 2.33E-06 MatchChrysene1.53E-06 5.74E-05 5.74E-06 Chrysene 3.53E-07 2.47E-09 1.32E-05 1.32E-06 1.53E-06 1.07E-08 5.74E-05 5.74E-06 MatchBenzo(b)fluoranthene 1.11E-06 4.16E-05 4.16E-06 Benzo(b)fluoranthene 9.91E-08 6.94E-10 3.72E-06 3.72E-07 1.11E-06 7.77E-09 4.16E-05 4.16E-06 MatchBenzo(k)fluoranthene 2.18E-07 8.18E-06 8.18E-07 Benzo(k)fluoranthene 1.55E-07 1.09E-09 5.82E-06 5.82E-07 2.18E-07 1.53E-09 8.18E-06 8.18E-07 MatchBenzo(a)pyrene 2.57E-07 9.64E-06 9.64E-07 Benzo(a)pyrene 1.88E-07 1.32E-09 7.05E-06 7.05E-07 2.57E-07 1.80E-09 9.64E-06 9.64E-07 MatchIndeno(1,2,3-cd)pyrene 4.14E-07 1.55E-05 1.55E-06 Indeno(1,2,3-cd)pyrene 3.75E-07 2.63E-09 1.41E-05 1.41E-06 4.14E-07 2.90E-09 1.55E-05 1.55E-06 MatchDibenz(a,h)anthracene 3.46E-07 1.30E-05 1.30E-06 Dibenz(a,h)anthracene 5.83E-07 4.08E-09 2.19E-05 2.19E-06 3.46E-07 2.42E-09 1.30E-05 1.30E-06 MatchBenzo(g,h,l)perylene 5.56E-07 2.09E-05 2.09E-06 Benzo(g,h,l)perylene 4.89E-07 3.42E-09 1.83E-05 1.83E-06 5.56E-07 3.89E-09 2.09E-05 2.09E-06 Match
AP-42 Table 3.3-1& Table 3.4-1
Emission Factor(lb/MMBtu)
AP-42 Table 3.3-2,Table 3.4-3, &Table 3.4-4
(1,3-Butadiene will not popluate if the engine size is greater than 600 hp. AP-42 does not list 1,3-Butadiene for engines greater than 600 hp.)
Emergency Engines should equal 100 hours of operation per year
Table 3.4-1>600 hp
Manufacturer Data,AP-42 Table 3.3-1,& Table 3.4-1
Page 1 of Version 1.1 February 21, 2019
7,000 BTU/hp-hrEquipment DetailsRating 1,060 hp = (791.1 kw)67 MMscf/yrOperational Hours 8,760 hours/year 0.18 MMscf/dayEngine Type 1343 Btu/scf lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check
Criteria Pollutant
EmissionStandards(g/hp-hr)Emission Factor(lb/MMBtu)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference NOX @ 90-105% Load 3.17E+00 2.22E-02 23.52 103.02 4.08E+00 2.86E-02 30.27 132.60 2.21E+00 1.55E-02 16.40 71.82NOX0.15 0.35 1.54 NOX @ <90% Load 1.94E+00 1.36E-02 14.39 63.05 8.47E-01 5.93E-03 6.28 27.53 2.27E+00 1.59E-02 16.84 73.77CO0.30 0.70 3.07 CO @ 90-105% Load 3.86E-01 2.70E-03 2.86 12.54 3.17E-01 2.22E-03 2.35 10.30 3.72E+00 2.60E-02 27.60 120.90PM101.94E-02 0.20 0.86 CO @ <90% Load 3.53E-01 2.47E-03 2.62 11.47 5.57E-01 3.90E-03 4.13 18.10 3.51E+00 2.46E-02 26.04 114.07PM2.5 1.94E-02 0.20 0.86 CO2 1.10E+02 7.70E-01 816.20 3574.96 Match 1.10E+02 7.70E-01 816.20 3574.96 Match 1.10E+02 7.70E-01 816.20 3574.96 Match
VOC 0.02 0.04 0.19 SO2 5.88E-04 4.12E-06 0.00 0.02 5.88E-04 4.12E-06 0.00 0.02 5.88E-04 4.12E-06 0.00 0.02SO23.13E-03 0.03 0.14 TOC 1.64E+00 1.15E-02 12.17 53.30 1.47E+00 1.03E-02 10.91 47.77 3.58E-01 2.51E-03 2.66 11.63HAP0.09 0.40 See Below Methane 1.45E+00 1.02E-02 10.76 47.12 1.25E+00 8.75E-03 9.28 40.62 2.30E-01 1.61E-03 1.71 7.47 MatchVOC1.20E-01 8.40E-04 0.89 3.90 1.18E-01 8.26E-04 0.88 3.83 2.96E-02 2.07E-04 0.22 0.96
Green House Gas Pollutant
Global Warming Potential Emission Factor(lb/MMBtu)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference PM10 - filterable 3.84E-02 2.69E-04 0.28 1.25 7.71E-05 5.40E-07 0.00 0.00 9.50E-03 6.65E-05 0.07 0.31CO2 (mass basis)1 1.10E+02 816 3,575 PM2.5 - filterable 3.84E-02 2.69E-04 0.28 1.25 7.71E-05 5.40E-07 0.00 0.00 9.50E-03 6.65E-05 0.07 0.31
Methane (mass basis)25 2.30E-01 2 7 PM - Condensable 9.91E-03 6.94E-05 0.07 0.32 9.91E-03 6.94E-05 0.07 0.32 9.91E-03 6.94E-05 0.07 0.32CO2e3,762 PM10 - Total 4.83E-02 0.36 1.57 9.99E-03 0.07 0.32 1.94E-02 0.14 0.63PM2.5 - Total 4.83E-02 0.36 1.57 9.99E-03 0.07 0.32 1.94E-02 0.14 0.63
Hazardous Air Pollutant
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference HAP lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check1,1,2,2-Tetrachloroethane 2.53E-05 0.00E+00 1,1,2,2-Tetrachloroethane 6.63E-05 4.64E-07 4.92E-04 2.15E-03 4.00E-05 2.80E-07 2.97E-04 1.30E-03 2.53E-05 1.77E-07 1.88E-04 8.22E-041,1,2-Trichloroethane 1.53E-05 1.14E-04 4.97E-04 1,1,2-Trichloroethane 5.27E-05 3.69E-07 3.91E-04 1.71E-03 3.18E-05 2.23E-07 2.36E-04 1.03E-03 1.53E-05 1.07E-07 1.14E-04 4.97E-04 Match1,3-Butadiene 6.63E-04 4.92E-03 2.15E-02 1,3-Butadiene 8.20E-04 5.74E-06 6.08E-03 2.66E-02 2.67E-04 1.87E-06 1.98E-03 8.68E-03 6.63E-04 4.64E-06 4.92E-03 2.15E-02 Match1,3-Dichloropropene 1.27E-05 9.42E-05 4.13E-04 1,3-Dichloropropene 4.38E-05 3.07E-07 3.25E-04 1.42E-03 2.64E-05 1.85E-07 1.96E-04 8.58E-04 1.27E-05 8.89E-08 9.42E-05 4.13E-04 Match2,2,4-Trimethylpentane 8.46E-04 5.92E-06 6.28E-03 2.75E-02 2.50E-04 1.75E-06 1.86E-03 8.12E-03 Match2-Methylnaphthalene 2.14E-05 1.50E-07 1.59E-04 6.95E-04 3.32E-05 2.32E-07 2.46E-04 1.08E-03 MatchAcenaphthene1.33E-06 9.31E-09 9.87E-06 4.32E-05 1.25E-06 8.75E-09 9.28E-06 4.06E-05 MatchAcenaphthylene3.17E-06 2.22E-08 2.35E-05 1.03E-04 5.53E-06 3.87E-08 4.10E-05 1.80E-04 MatchAcetaldehyde2.79E-03 2.07E-02 9.07E-02 Acetaldehyde 7.76E-03 5.43E-05 5.76E-02 2.52E-01 8.36E-03 5.85E-05 6.20E-02 2.72E-01 2.79E-03 1.95E-05 2.07E-02 9.07E-02 MatchAcrolein2.63E-03 1.95E-02 8.55E-02 Acrolein 7.78E-03 5.45E-05 5.77E-02 2.53E-01 5.14E-03 3.60E-05 3.81E-02 1.67E-01 2.63E-03 1.84E-05 1.95E-02 8.55E-02 MatchAnthracene7.18E-07 5.03E-09 5.33E-06 2.33E-05 Match MatchBenz(a)anthracene 3.36E-07 2.35E-09 2.49E-06 1.09E-05 Match MatchBenzene1.58E-03 1.17E-02 5.13E-02 Benzene 1.94E-03 1.36E-05 1.44E-02 6.30E-02 4.40E-04 3.08E-06 3.26E-03 1.43E-02 1.58E-03 1.11E-05 1.17E-02 5.13E-02 MatchBenzo(a)pyrene 5.68E-09 3.98E-11 4.21E-08 1.85E-07 Match MatchBenzo(b)fluoranthene 8.51E-09 5.96E-11 6.31E-08 2.77E-07 1.66E-07 1.16E-09 1.23E-06 5.39E-06 MatchBenzo(e)pyrene 2.34E-08 1.64E-10 1.74E-07 7.60E-07 4.15E-07 2.91E-09 3.08E-06 1.35E-05 Matchbenzo(g,h,i)perylene 2.48E-08 1.74E-10 1.84E-07 8.06E-07 4.14E-07 2.90E-09 3.07E-06 1.35E-05 MatchBenzo(k)fluoranthene 4.26E-09 2.98E-11 3.16E-08 1.38E-07 Match MatchBiphenyl3.95E-06 2.77E-08 2.93E-05 1.28E-04 2.12E-04 1.48E-06 1.57E-03 6.89E-03 MatchCarbon Tetrachloride 1.77E-05 1.31E-04 5.75E-04 Carbon Tetrachloride 6.07E-05 4.25E-07 4.50E-04 1.97E-03 3.67E-05 2.57E-07 2.72E-04 1.19E-03 1.77E-05 1.24E-07 1.31E-04 5.75E-04 MatchChlorobenzene1.29E-05 9.57E-05 4.19E-04 Chlorobenzene 4.44E-05 3.11E-07 3.29E-04 1.44E-03 3.04E-05 2.13E-07 2.26E-04 9.88E-04 1.29E-05 9.03E-08 9.57E-05 4.19E-04 MatchChloroform1.37E-05 1.02E-04 4.45E-04 Chloroform 4.71E-05 3.30E-07 3.49E-04 1.53E-03 2.85E-05 2.00E-07 2.11E-04 9.26E-04 1.37E-05 9.59E-08 1.02E-04 4.45E-04 MatchChrysene6.72E-07 4.70E-09 4.99E-06 2.18E-05 6.93E-07 4.85E-09 5.14E-06 2.25E-05 MatchEthylbenzene2.48E-05 1.84E-04 8.06E-04 Ethylbenzene 1.08E-04 7.56E-07 8.01E-04 3.51E-03 3.97E-05 2.78E-07 2.95E-04 1.29E-03 2.48E-05 1.74E-07 1.84E-04 8.06E-04 MatchEthylene Dibromide 2.13E-05 1.58E-04 6.92E-04 Ethylene Dibromide 7.34E-05 5.14E-07 5.45E-04 2.39E-03 4.43E-05 3.10E-07 3.29E-04 1.44E-03 2.13E-05 1.49E-07 1.58E-04 6.92E-04 MatchFluoranthene3.61E-07 2.53E-09 2.68E-06 1.17E-05 1.11E-06 7.77E-09 8.24E-06 3.61E-05 MatchFluorene1.69E-06 1.18E-08 1.25E-05 5.49E-05 5.67E-06 3.97E-08 4.21E-05 1.84E-04 MatchFormaldehyde0.001 0.00 1.02E-02 Formaldehyde 5.52E-02 3.86E-04 4.10E-01 1.79E+00 5.28E-02 3.70E-04 3.92E-01 1.72E+00 2.05E-02 1.44E-04 1.52E-01 6.66E-01Indeno(1,2,3-c,d)pyrene 9.93E-09 6.95E-11 7.37E-08 3.23E-07 Match MatchMethanol3.06E-03 2.27E-02 9.94E-02 Methanol 2.48E-03 1.74E-05 1.84E-02 8.06E-02 2.50E-03 1.75E-05 1.86E-02 8.12E-02 3.06E-03 2.14E-05 2.27E-02 9.94E-02 MatchMethylene Chloride 4.12E-05 3.06E-04 1.34E-03 Methylene Chloride 1.47E-04 1.03E-06 1.09E-03 4.78E-03 2.00E-05 1.40E-07 1.48E-04 6.50E-04 4.12E-05 2.88E-07 3.06E-04 1.34E-03 Matchn-Hexane 4.45E-04 3.12E-06 3.30E-03 1.45E-02 1.11E-03 7.77E-06 8.24E-03 3.61E-02 MatchNaphthalene9.71E-05 7.20E-04 3.16E-03 Naphthalene 9.63E-05 6.74E-07 7.15E-04 3.13E-03 7.44E-05 5.21E-07 5.52E-04 2.42E-03 9.71E-05 6.80E-07 7.20E-04 3.16E-03 MatchPAH1.41E-04 1.05E-03 4.58E-03 PAH 1.34E-04 9.38E-07 9.94E-04 4.35E-03 2.69E-05 1.88E-07 2.00E-04 8.74E-04 1.41E-04 9.87E-07 1.05E-03 4.58E-03 MatchPerylene4.97E-09 3.48E-11 3.69E-08 1.62E-07 Match MatchPhenanthrene3.53E-06 2.47E-08 2.62E-05 1.15E-04 1.04E-05 7.28E-08 7.72E-05 3.38E-04 MatchPhenol4.21E-05 2.95E-07 3.12E-04 1.37E-03 2.40E-05 1.68E-07 1.78E-04 7.80E-04 MatchPyrene5.84E-07 4.09E-09 4.33E-06 1.90E-05 1.36E-06 9.52E-09 1.01E-05 4.42E-05 MatchStyrene1.19E-05 8.83E-05 3.87E-04 Styrene 5.48E-05 3.84E-07 4.07E-04 1.78E-03 2.36E-05 1.65E-07 1.75E-04 7.67E-04 1.19E-05 8.33E-08 8.83E-05 3.87E-04 MatchTetrachloroethaneMatch2.48E-06 1.74E-08 1.84E-05 8.06E-05 MatchToluene5.58E-04 4.14E-03 1.81E-02 Toluene 9.63E-04 6.74E-06 7.15E-03 3.13E-02 4.08E-04 2.86E-06 3.03E-03 1.33E-02 5.58E-04 3.91E-06 4.14E-03 1.81E-02 MatchVinyl Chloride 7.18E-06 5.33E-05 2.33E-04 Vinyl Chloride 2.47E-05 1.73E-07 1.83E-04 8.03E-04 1.49E-05 1.04E-07 1.11E-04 4.84E-04 7.18E-06 5.03E-08 5.33E-05 2.33E-04 MatchXylene1.95E-04 1.45E-03 6.34E-03 Xylene 2.68E-04 1.88E-06 1.99E-03 8.71E-03 1.84E-04 1.29E-06 1.37E-03 5.98E-03 1.95E-04 1.37E-06 1.45E-03 6.34E-03 Match
Total HAP 0.59 2.58 0.54 2.35 0.24 1.05
2-Stroke Lean-Burn 4-Stroke Lean-Burn 4-Stroke Rich-Burn
Manufacturer Data,AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
Emission Factor(lb/MMBtu)
AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
(Some HAP do not popluate based on the type of engine selected. AP-42 does not list certain HAP for certain types of engines.)
Natural Gas-Fired Engines
Emergency Engines should equal 100 hours of operation per year4-Stroke Rich-Burn
Page 2 of Version 1.1 February 21, 2019
7,000 BTU/hp-hrEquipment Details 1387 MMscf/yrRating25,000 hp = (18656.8 kw)3.8 MMscf/dayOperational Hours 8,760 hours/year 1343 Btu/scfEngine Type lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check
Criteria Pollutant
EmissionStandards(g/hp-hr)Emission Factor(lb/MMBtu)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference NOX @ 90-105% Load 3.17E+00 2.22E-02 554.75 2429.81 4.08E+00 2.86E-02 714.00 3127.32 2.21E+00 1.55E-02 386.75 1693.97NOX0.15 8.27 36.21 NOX @ <90% Load 1.94E+00 1.36E-02 339.50 1487.01 8.47E-01 5.93E-03 148.23 649.23 2.27E+00 1.59E-02 397.25 1739.96CO0.30 16.53 72.42 CO @ 90-105% Load 3.86E-01 2.70E-03 67.55 295.87 3.17E-01 2.22E-03 55.48 242.98 3.72E+00 2.60E-02 651.00 2851.38PM100.01 0.55 2.41 CO @ <90% Load 3.53E-01 2.47E-03 61.78 270.57 5.57E-01 3.90E-03 97.48 426.94 3.51E+00 2.46E-02 614.25 2690.42PM2.5 0.01 0.55 2.41 CO2 1.10E+02 7.70E-01 19250.00 84315.00 Match 1.10E+02 7.70E-01 19250.00 84315.00 Match 1.10E+02 7.70E-01 19250.00 84315.00 Match
VOC 0.03 1.65 7.24 SO2 5.88E-04 4.12E-06 0.10 0.45 5.88E-04 4.12E-06 0.10 0.45 5.88E-04 4.12E-06 0.10 0.45SO23.13E-03 0.67 2.92 TOC 1.64E+00 1.15E-02 287.00 1257.06 1.47E+00 1.03E-02 257.25 1126.76 3.58E-01 2.51E-03 62.65 274.41HAP2.14 9.38 See Below Methane 1.45E+00 1.02E-02 253.75 1111.43 1.25E+00 8.75E-03 218.75 958.13 2.30E-01 1.61E-03 40.25 176.30 MatchVOC1.20E-01 8.40E-04 21.00 91.98 1.18E-01 8.26E-04 20.65 90.45 2.96E-02 2.07E-04 5.18 22.69
Green House Gas Pollutant
Global Warming Potential Emission Factor(lb/MMBtu)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference PM10 - filterable 3.84E-02 2.69E-04 6.72 29.43 7.71E-05 5.40E-07 0.01 0.06 9.50E-03 6.65E-05 1.66 7.28CO2 (mass basis)1 1.10E+02 19,250 84,315 PM2.5 - filterable 3.84E-02 2.69E-04 6.72 29.43 7.71E-05 5.40E-07 0.01 0.06 9.50E-03 6.65E-05 1.66 7.28
Methane (mass basis)25 2.30E-01 40 176 PM - Condensable 9.91E-03 6.94E-05 1.73 7.60 9.91E-03 6.94E-05 1.73 7.60 9.91E-03 6.94E-05 1.73 7.60CO2e88,722 PM10 - Total 4.83E-02 8.45 37.03 9.99E-03 1.75 7.66 1.94E-02 3.40 14.88PM2.5 - Total 4.83E-02 8.45 37.03 9.99E-03 1.75 7.66 1.94E-02 3.40 14.88
Hazardous Air Pollutant
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference HAP lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check lb/MMBtu lb/hp-hr lb/hr Ton/year Check1,1,2,2-Tetrachloroethane 2.53E-05 4.43E-03 1.94E-02 1,1,2,2-Tetrachloroethane 6.63E-05 4.64E-07 1.16E-02 5.08E-02 4.00E-05 2.80E-07 7.00E-03 3.07E-02 2.53E-05 1.77E-07 4.43E-03 1.94E-02 Match1,1,2-Trichloroethane 1.53E-05 2.68E-03 1.17E-02 1,1,2-Trichloroethane 5.27E-05 3.69E-07 9.22E-03 4.04E-02 3.18E-05 2.23E-07 5.57E-03 2.44E-02 1.53E-05 1.07E-07 2.68E-03 1.17E-02 Match1,3-Butadiene 6.63E-04 1.16E-01 5.08E-01 1,3-Butadiene 8.20E-04 5.74E-06 1.44E-01 6.29E-01 2.67E-04 1.87E-06 4.67E-02 2.05E-01 6.63E-04 4.64E-06 1.16E-01 5.08E-01 Match1,3-Dichloropropene 1.27E-05 2.22E-03 9.73E-03 1,3-Dichloropropene 4.38E-05 3.07E-07 7.67E-03 3.36E-02 2.64E-05 1.85E-07 4.62E-03 2.02E-02 1.27E-05 8.89E-08 2.22E-03 9.73E-03 Match2,2,4-Trimethylpentane 8.46E-04 5.92E-06 1.48E-01 6.48E-01 2.50E-04 1.75E-06 4.38E-02 1.92E-01 Match2-Methylnaphthalene 2.14E-05 1.50E-07 3.75E-03 1.64E-02 3.32E-05 2.32E-07 5.81E-03 2.54E-02 MatchAcenaphthene1.33E-06 9.31E-09 2.33E-04 1.02E-03 1.25E-06 8.75E-09 2.19E-04 9.58E-04 MatchAcenaphthylene3.17E-06 2.22E-08 5.55E-04 2.43E-03 5.53E-06 3.87E-08 9.68E-04 4.24E-03 MatchAcetaldehyde2.79E-03 4.88E-01 2.14E+00 Acetaldehyde 7.76E-03 5.43E-05 1.36E+00 5.95E+00 8.36E-03 5.85E-05 1.46E+00 6.41E+00 2.79E-03 1.95E-05 4.88E-01 2.14E+00 MatchAcrolein2.63E-03 4.60E-01 2.02E+00 Acrolein 7.78E-03 5.45E-05 1.36E+00 5.96E+00 5.14E-03 3.60E-05 9.00E-01 3.94E+00 2.63E-03 1.84E-05 4.60E-01 2.02E+00 MatchAnthracene7.18E-07 5.03E-09 1.26E-04 5.50E-04 Match MatchBenz(a)anthracene 3.36E-07 2.35E-09 5.88E-05 2.58E-04 Match MatchBenzene1.58E-03 2.77E-01 1.21E+00 Benzene 1.94E-03 1.36E-05 3.40E-01 1.49E+00 4.40E-04 3.08E-06 7.70E-02 3.37E-01 1.58E-03 1.11E-05 2.77E-01 1.21E+00 MatchBenzo(a)pyrene 5.68E-09 3.98E-11 9.94E-07 4.35E-06 Match MatchBenzo(b)fluoranthene 8.51E-09 5.96E-11 1.49E-06 6.52E-06 1.66E-07 1.16E-09 2.91E-05 1.27E-04 MatchBenzo(e)pyrene 2.34E-08 1.64E-10 4.10E-06 1.79E-05 4.15E-07 2.91E-09 7.26E-05 3.18E-04 Matchbenzo(g,h,i)perylene 2.48E-08 1.74E-10 4.34E-06 1.90E-05 4.14E-07 2.90E-09 7.25E-05 3.17E-04 MatchBenzo(k)fluoranthene 4.26E-09 2.98E-11 7.46E-07 3.27E-06 Match MatchBiphenyl3.95E-06 2.77E-08 6.91E-04 3.03E-03 2.12E-04 1.48E-06 3.71E-02 1.62E-01 MatchCarbon Tetrachloride 1.77E-05 3.10E-03 1.36E-02 Carbon Tetrachloride 6.07E-05 4.25E-07 1.06E-02 4.65E-02 3.67E-05 2.57E-07 6.42E-03 2.81E-02 1.77E-05 1.24E-07 3.10E-03 1.36E-02 MatchChlorobenzene1.29E-05 2.26E-03 9.89E-03 Chlorobenzene 4.44E-05 3.11E-07 7.77E-03 3.40E-02 3.04E-05 2.13E-07 5.32E-03 2.33E-02 1.29E-05 9.03E-08 2.26E-03 9.89E-03 MatchChloroform1.37E-05 2.40E-03 1.05E-02 Chloroform 4.71E-05 3.30E-07 8.24E-03 3.61E-02 2.85E-05 2.00E-07 4.99E-03 2.18E-02 1.37E-05 9.59E-08 2.40E-03 1.05E-02 MatchChrysene6.72E-07 4.70E-09 1.18E-04 5.15E-04 6.93E-07 4.85E-09 1.21E-04 5.31E-04 MatchEthylbenzene2.48E-05 4.34E-03 1.90E-02 Ethylbenzene 1.08E-04 7.56E-07 1.89E-02 8.28E-02 3.97E-05 2.78E-07 6.95E-03 3.04E-02 2.48E-05 1.74E-07 4.34E-03 1.90E-02 MatchEthylene Dibromide 2.13E-05 3.73E-03 1.63E-02 Ethylene Dibromide 7.34E-05 5.14E-07 1.28E-02 5.63E-02 4.43E-05 3.10E-07 7.75E-03 3.40E-02 2.13E-05 1.49E-07 3.73E-03 1.63E-02 MatchFluoranthene3.61E-07 2.53E-09 6.32E-05 2.77E-04 1.11E-06 7.77E-09 1.94E-04 8.51E-04 MatchFluorene1.69E-06 1.18E-08 2.96E-04 1.30E-03 5.67E-06 3.97E-08 9.92E-04 4.35E-03 MatchFormaldehyde0.001 2.05E-02 0.06 2.41E-01 Formaldehyde 5.52E-02 3.86E-04 9.66E+00 4.23E+01 5.28E-02 3.70E-04 9.24E+00 4.05E+01 2.05E-02 1.44E-04 3.59E+00 1.57E+01Indeno(1,2,3-c,d)pyrene 9.93E-09 6.95E-11 1.74E-06 7.61E-06 Match MatchMethanol3.06E-03 5.36E-01 2.35E+00 Methanol 2.48E-03 1.74E-05 4.34E-01 1.90E+00 2.50E-03 1.75E-05 4.38E-01 1.92E+00 3.06E-03 2.14E-05 5.36E-01 2.35E+00 MatchMethylene Chloride 4.12E-05 7.21E-03 3.16E-02 Methylene Chloride 1.47E-04 1.03E-06 2.57E-02 1.13E-01 2.00E-05 1.40E-07 3.50E-03 1.53E-02 4.12E-05 2.88E-07 7.21E-03 3.16E-02 Matchn-Hexane 4.45E-04 3.12E-06 7.79E-02 3.41E-01 1.11E-03 7.77E-06 1.94E-01 8.51E-01 MatchNaphthalene9.71E-05 1.70E-02 7.44E-02 Naphthalene 9.63E-05 6.74E-07 1.69E-02 7.38E-02 7.44E-05 5.21E-07 1.30E-02 5.70E-02 9.71E-05 6.80E-07 1.70E-02 7.44E-02 MatchPAH1.41E-04 2.47E-02 1.08E-01 PAH 1.34E-04 9.38E-07 2.35E-02 1.03E-01 2.69E-05 1.88E-07 4.71E-03 2.06E-02 1.41E-04 9.87E-07 2.47E-02 1.08E-01 MatchPerylene4.97E-09 3.48E-11 8.70E-07 3.81E-06 Match MatchPhenanthrene3.53E-06 2.47E-08 6.18E-04 2.71E-03 1.04E-05 7.28E-08 1.82E-03 7.97E-03 MatchPhenol4.21E-05 2.95E-07 7.37E-03 3.23E-02 2.40E-05 1.68E-07 4.20E-03 1.84E-02 MatchPyrene5.84E-07 4.09E-09 1.02E-04 4.48E-04 1.36E-06 9.52E-09 2.38E-04 1.04E-03 MatchStyrene1.19E-05 2.08E-03 9.12E-03 Styrene 5.48E-05 3.84E-07 9.59E-03 4.20E-02 2.36E-05 1.65E-07 4.13E-03 1.81E-02 1.19E-05 8.33E-08 2.08E-03 9.12E-03 MatchTetrachloroethaneMatch2.48E-06 1.74E-08 4.34E-04 1.90E-03 MatchToluene5.58E-04 9.77E-02 4.28E-01 Toluene 9.63E-04 6.74E-06 1.69E-01 7.38E-01 4.08E-04 2.86E-06 7.14E-02 3.13E-01 5.58E-04 3.91E-06 9.77E-02 4.28E-01 MatchVinyl Chloride 7.18E-06 1.26E-03 5.50E-03 Vinyl Chloride 2.47E-05 1.73E-07 4.32E-03 1.89E-02 1.49E-05 1.04E-07 2.61E-03 1.14E-02 7.18E-06 5.03E-08 1.26E-03 5.50E-03 MatchXylene1.95E-04 3.41E-02 1.49E-01 Xylene 2.68E-04 1.88E-06 4.69E-02 2.05E-01 1.84E-04 1.29E-06 3.22E-02 1.41E-01 1.95E-04 1.37E-06 3.41E-02 1.49E-01 Match
Total HAP 13.92 60.96 12.63 55.34 5.67 24.85
2-Stroke Lean-Burn 4-Stroke Lean-Burn 4-Stroke Rich-Burn
Manufacturer Data,AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
Emission Factor(lb/MMBtu)
AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
(Some HAP do not popluate based on the type of engine selected. AP-42 does not list certain HAP for certain types of engines.)
Natural Gas-Fired Engines
Emergency Engines should equal 100 hours of operation per year4-Stroke Rich-Burn
Page 3 of Version 1.1 February 21, 2019
7,000 BTU/hp-hr
Equipment Details 868 MMscf/yr
Rating 18,270 hp = (13634.4 kw)2.38 MMscf/day
Operational Hours 8,760 hours/year 1343 Btu/scfEngine Type
Criteria Pollutant
Emission
Standards(g/hp-hr)Emission Factor(lb/MMBtu)
Emission
Rate(lbs/hr)
Emission
Total(tons/year)Reference
NOX 0.33 13.29 58.22CO0.20 8.06 35.28
PM10 6.60E-03 0.88 3.85PM2.5 6.60E-03 0.88 3.85
VOC 0.12 4.63 20.29SO23.13E-03 0.42 1.83
HAP 0.13 0.56 See Below
Green House Gas Pollutant
Global Warming Potential Emission Factor(lb/MMBtu)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)ReferenceCO2 (mass basis)1 #REF!#REF!#REF!
Methane (mass basis)25 #REF!#REF!#REF!CO2e #REF!
Hazardous Air Pollutant
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference0.00E+00 0.00E+000.00E+00 0.00E+001,3-Butadiene 4.30E-07 5.50E-05 2.41E-040.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+00Acetaldehyde4.00E-05 5.12E-03 2.24E-02Acrolein6.40E-06 8.18E-04 3.59E-030.00E+00 0.00E+000.00E+00 0.00E+00Benzene1.20E-05 1.53E-03 6.72E-030.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+00Ethylbenzene3.20E-05 4.09E-03 1.79E-020.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+00Formaldehyde7.10E-04 9.08E-02 3.98E-010.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+00Naphthalene1.30E-06 1.66E-04 7.28E-04PAH0.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+000.00E+00 0.00E+00Toluene1.30E-04 1.66E-02 7.28E-020.00E+00 0.00E+00Xylene6.40E-05 8.18E-03 3.59E-02
Emission Factor(lb/MMBtu)
AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
(Some HAP do not
popluate based on
the type of engine
selected. AP-42 does not list certain HAP for certain types of engines.)
Turbine
Emergency Engines should
equal 100 hours of operation per year4-Stroke Lean-Burn
Manufacturer Data,AP-42 Table 3.2-1,Table 3.2-2, &Table 3.2-3
AP-42 Table 3.2-1,
Table 3.2-2, &
Table 3.2-3
Page 4 of Version 1.1 February 21, 2019
Criteria
Pollutant
DAQ
Emission
Total
(tons/year)
in NOI
(tons//year)Difference
NOX 96.7 96.6 -0.1
CO 111.1 111.4 0.3
PM10 7.2 7.2 0.0
PM2.5 7.2 7.2 0.0
SO2 4.9 4.9 0.0
VOC 36.5 36.2 -0.3
HAP 10.3419 10.5 0.1
VOCs
Dehyrdators 5.72
Truck Load out 2.67
Fugitives Leaks 0.4

2024 AO
Criteria
Pollutant AO Updated AO
NOX 96.59 96.110 -0.480
CO 111.42 111.020 -0.400
PM10 7.17 7.134 -0.036
PM2.5 7.17 7.134 -0.036
SO2 4.88 4.877 -0.003
VOC 36.21 27.794 -8.416
0.000
HAP 10.47 9.917 -0.553
0
CO2e 183353 182702.41 -650.59
EG Boilers Truck Loading Reduction
Benzene 0.17 0.27 0.44
Toluene 0.01 0.06 0.07
Formaldehyde 0.00
Ethylbenzne 0.00 0.02 0.02
tpy
Xylenes 0.00 0.02 0.02
Gen HAPs 0.01 0.01
0.55
Heating Value of Natural Gas 1020 BTU/scf or MMBtu/MMscf
Equipment Details 3.59 MMscf/yr
Rating 1 MMBtu/hour 1343 Btu/scf NOx Size Table 1.4-1 lb/10^6 scf lb/MMBtu lb/hr Ton/year CheckOperational Hours 8,760 hours/year >100 MMBtu/hr Uncontrolled - Pre NSPS (Subparts D & Db)280 0.2745 0.30 1.32FiringNormal>100 MMBtu/hr Uncontrolled - Post NSPS (Subparts D & Db)190 0.1863 0.20 0.90>100 MMBtu/hr Controlled - Low Nox burners 140 0.1373 0.15 0.66
Criteria Pollutant Concentration(ppm)
Emission Factor(lb/10^6 scf)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference >100 MMBtu/hr Controlled - Flue gas recirculation (FGR)100 0.0980 0.11 0.47NOX1000.06 0.25 <100 MMBtu/hr Uncontrolled 100 0.0980 0.11 0.47CO840.05 0.21 <100 MMBtu/hr Controlled - Low Nox burners 50 0.0490 0.05 0.24PM107.6 0.00 0.02 <100 MMBtu/hr Controlled - Low Nox burners/FGR 32 0.0314 0.03 0.15PM2.5 7.6 0.00 0.02 Tangential-Fired Uncontrolled 170 0.1667 0.18 0.80SO20.6 0.00 0.00 Tangential-Fired Controlled - FGR 76 0.0745 0.08 0.36VOC5.5 0.00 0.01Lead0.0005 0.00 0.00 CO Size Table 1.4-1 lb/10^6 scf lb/MMBtu lb/hr Ton/year CheckHAP0.00 0.0047 See Below >100 MMBtu/hr Uncontrolled - Pre NSPS (Subparts D & Db)84 0.0824 0.09 0.40>100 MMBtu/hr Uncontrolled - Post NSPS (Subparts D & Db)84 0.0824 0.09 0.40
Green House Gas Pollutant
Global Warming Potential
Emission Factor(lb/10^6 scf)
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference >100 MMBtu/hr Controlled - Low Nox burners 84 0.0824 0.09 0.40CO2 (mass basis)1 120,000 129 567 >100 MMBtu/hr Controlled - Flue gas recirculation (FGR)84 0.0824 0.09 0.40Methane (mass basis)25 2.3 0.00 0.01 <100 MMBtu/hr Uncontrolled 84 0.0824 0.09 0.40N2O (mass basis)298 2.2 0.00 0.01 <100 MMBtu/hr Controlled - Low Nox burners 84 0.0824 0.09 0.40CO2e570<100 MMBtu/hr Controlled - Low Nox burners/FGR 84 0.0824 0.09 0.40Tangential-Fired Uncontrolled 24 0.0235 0.03 0.11
Hazardous Air Pollutant
EmissionRate(lbs/hr)
EmissionTotal(tons/year)Reference Tangential-Fired Controlled - FGR 98 0.0961 0.11 0.462-Methylnaphthalene 2.40E-05 0.00 5.93E-083-Methylchloranthrene 1.80E-06 0.00 4.45E-09 Any Size Table 1.4-2 lb/10^6 scf lb/MMBtu lb/hr Ton/year Check7,12-Dimethylbenz(a)anthracene 1.60E-05 0.00 3.96E-08 CO2 120,000 117.6471 129 567 MatchAcenaphthene1.80E-06 0.00 4.45E-09 Lead 0.0005 0.0000 0.00 0.00 MatchAcenaphthylene1.80E-06 0.00 4.45E-09 N2O Uncontrolled 2.2 0.0022 0.00 0.01 MatchAnthracene2.40E-06 0.00 5.93E-09 Controlled - Low Nox burners 0.64 0.0006 0.00 0.00Benz(a)anthracene 1.80E-06 0.00 4.45E-09 PM (total)7.6 0.0075 0.01 0.04Benzene2.10E-03 0.00 5.19E-06 PM (cond)5.7 0.0056 0.01 0.03Benzo(a)pyrene 1.20E-06 0.00 2.97E-09 PM (filter)1.9 0.0019 0.00 0.01Benzo(b)fluoranthene 1.80E-06 0.00 4.45E-09 SO2 0.6 0.0006 0.00 0.00Benzo(g,h,i)perylene 1.20E-06 0.00 2.97E-09 TOC 11 0.0108 0.01 0.05Benzo(k)fluoranthene 1.80E-06 0.00 4.45E-09 Methane 2.3 0.0023 0.00 0.01 MatchChrysene1.80E-06 0.00 4.45E-09 VOC 5.5 0.0054 0.01 0.03Dibenzo(a,h)anthracene 1.20E-06 0.00 2.97E-09Dichlorobenzene1.20E-03 0.00 2.97E-06 Global Warming Potential lb/hr Ton/yearFluoranthene3.00E-06 0.00 7.42E-09 CO2 1 129 567Fluorene2.80E-06 0.00 6.92E-09 Methane 25 0 0Formaldehyde7.50E-02 0.00 1.85E-04 N2O 298 1 3Hexane1.80E+00 0.00 4.45E-03 CO2e Total CO2e 130 570 MatchIndeno(1,2,3-cd)pyrene 1.80E-06 0.00 4.45E-09Naphthalene6.10E-04 0.00 1.51E-06 HAP - Organic Table 1.4-3 lb/10^6 scf lb/MMBtu lb/hr Ton/year CheckPhenanathrene1.70E-05 0.00 4.20E-08 2-Methylnaphthalene 2.40E-05 2.35E-08 2.59E-08 1.13E-07Pyrene5.00E-06 0.00 1.24E-08 3-Methylchloranthrene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Toluene3.40E-03 0.00 8.41E-06 7,12-Dimethylbenz(a)anthracene 1.60E-05 1.57E-08 1.73E-08 7.56E-08Arsenic2.00E-04 0.00 4.94E-07 Acenaphthene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Beryllium1.20E-05 0.00 2.97E-08 Acenaphthylene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Cadmium1.10E-03 0.00 2.72E-06 Anthracene 2.40E-06 2.35E-09 2.59E-09 1.13E-08Chromium1.40E-03 0.00 3.46E-06 Benz(a)anthracene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Cobalt8.40E-05 0.00 2.08E-07 Benzene 2.10E-03 2.06E-06 2.26E-06 9.92E-06Manganese3.80E-04 0.00 9.39E-07 Benzo(a)pyrene 1.20E-06 1.18E-09 1.29E-09 5.67E-09Mercury2.60E-04 0.00 6.43E-07 Benzo(b)fluoranthene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Nickel2.10E-03 0.00 5.19E-06 Benzo(g,h,i)perylene 1.20E-06 1.18E-09 1.29E-09 5.67E-09Selenium2.40E-05 0.00 5.93E-08 Benzo(k)fluoranthene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Chrysene1.80E-06 1.76E-09 1.94E-09 8.50E-09Dibenzo(a,h)anthracene 1.20E-06 1.18E-09 1.29E-09 5.67E-09Dichlorobenzene1.20E-03 1.18E-06 1.29E-06 5.67E-06Fluoranthene3.00E-06 2.94E-09 3.24E-09 1.42E-08Fluorene2.80E-06 2.75E-09 3.02E-09 1.32E-08Formaldehyde7.50E-02 7.35E-05 8.09E-05 3.54E-04Hexane1.80E+00 1.76E-03 1.94E-03 8.50E-03Indeno(1,2,3-cd)pyrene 1.80E-06 1.76E-09 1.94E-09 8.50E-09Naphthalene6.10E-04 5.98E-07 6.58E-07 2.88E-06Phenanathrene1.70E-05 1.67E-08 1.83E-08 8.03E-08Pyrene5.00E-06 4.90E-09 5.39E-09 2.36E-08Toluene3.40E-03 3.33E-06 3.67E-06 1.61E-05
HAP - Metal Table 1.4-4 lb/10^6 scf lb/MMBtu lb/hr Ton/year CheckArsenic2.00E-04 1.96E-07 2.16E-07 9.45E-07Beryllium1.20E-05 1.18E-08 1.29E-08 5.67E-08Cadmium1.10E-03 1.08E-06 1.19E-06 5.20E-06Chromium1.40E-03 1.37E-06 1.51E-06 6.61E-06Cobalt8.40E-05 8.24E-08 9.06E-08 3.97E-07Manganese3.80E-04 3.73E-07 4.10E-07 1.79E-06Mercury2.60E-04 2.55E-07 2.80E-07 1.23E-06Nickel2.10E-03 2.06E-06 2.26E-06 9.92E-06Selenium2.40E-05 2.35E-08 2.59E-08 1.13E-07
Total HAP Total HAP lb/hr Ton/year Check0.00 0.01
ppm to lb/MMBtu Conversion.
Source: AQMD Permit Sample Evaluation Natural Gas Fired Boiler 5-20 MMBTU/HR, 2007
Nox Molecular Weight 46.1 lb/lb-moleCO Molecular Weight 28.01 lb/lb-mole
Concentration lb/MMBtu lb/hr Ton/year CheckNox000.00 0.00CO000.00 0.00
AP-42 Table 1.4-3
AP-42 Table 1.4-4
Natural Gas-Fired Boilers & Heaters
Manufacturer Dataor AP-42 Table 1.4-1
AP-42 Table 1.4-2
AP-42 Table 1.4-2&Table A-1 toSubpart A of Part 98
Emission Factor(lb/10^6 scf)
Page 9 of Version 1.0 November 29, 2018

Corporate Headquarters
255 Fillmore St
Denver, CO 80206
crusoe.ai

August 12, 2024

Utah Division of Air Quality
195 North 1950 West
Salt Lake City, UT 84114-4820

Subject: Crusoe Energy Systems, Inc.
Duchesne Data Center Power Station
AO DAQE- AN161210002-23
attn.: NSR Section. [R307-401-18]

To Whom it may Concern,

Crusoe Energy Systems, Inc. (Crusoe Energy) is submitting this letter to notify UDAQ of the
status of construction or modification of units at the Duchesne Data Center Power Station
permitted under Utah Division of Air Quality Approval Order DAQE-AN161210002-23 required
by permit Condition I.8. A summary of the engines and turbine that began operation are below:

Emissions ID – Unit
Number
Date of Operation
Commencement
Notice of Startup
Submission Date
EU02 – Unit 1362 6/9/2023 6/12/2023
EU02 – Unit 1361 6/10/2023 6/12/2023
EU02 – Unit 1358 6/12/2023 6/12/2023
EU02 – Unit 1283 6/12/2023 6/12/2023
EU02 – Unit 1251 6/13/2023 6/20/2023
EU02 – Unit 1318 6/14/2023 6/20/2023
EU02 – Unit 1364 6/15/2023 6/20/2023
EU02 – Unit 1363 6/17/2023 6/20/2023
EU02 – Unit 1254 6/18/2023 6/20/2023
EU02 – Unit 1365 6/16/2023 6/20/2023
EU01 – Booster #1 7/23/2023 8/2/2023
EU01 – Booster #1 7/23/2023 8/2/2023
EU03 – Turbine 7/23/2023 8/2/2023

At this time, the two (2) emergency engine generators have not operated. The two (2) ethylene
glycol dehydrators, two (2) boilers, and the three (3) pressurized storage tanks covered under
Approval Order DAQE-AN161210002-23 have not been constructed or installed at the Duchesne
Data Center Power Station.

Name and Address of Owner
Crusoe Energy Systems, Inc.
255 Fillmore St. Denver CO, 80206

Facility Name and Location
Duchesne Data Center PowerStation
Universal Transverse Mercator (UTM) Datum NAD83 Zone 12
567,859 meters easting, 4,460,140 meters northing
Duchesne County, Utah
Coordinates: 40.28899, -110.20166

Should you have any technical questions or need additional information you may contact me at
[e-mail] or [phone].

Sincerely,

Laura Pritchard
Environmental Specialist