HomeMy WebLinkAboutDAQ-2024-008380
June 6 , 2024
David Beatty
Utah Department of Environmental Quality
Title V Section
195 North 1950 West
Salt Lake City, Utah 84116
submitted via email: dbeatty@utah.gov
Subject: Crusoe Energy Systems, Inc. Duchesne Data Center Power Station - Initial Title V Operating
Permit Application
Duchesne County, Utah
On behalf of Crusoe Energy Systems, Inc (Crusoe) please find enclosed the initial Title V Operating Permit
Application for the Duchesne Data Center Power Station currently permitted under Approval Order (AO)
DAQE-AN161210002-23 dated February 13, 2023. Throughout this application, the Facility name is shortened
for ease of reading and review to either “Facility” or “Snapper Facility” as it is commonly referred to
operationally.
The Facility began operation on June 9, 2023 and is submitting this application within 12 months of
commencement of operation. At the time of application submittal the following equipment is installed:
Two (2) 530 horsepower (hp) Waukesha VGF H24SE compressor engines each fitted with a non-selective
catalytic reduction (NSCR) device,
Ten (10) 2,500 hp Waukesha 9394GSI generator engines each fitted with a NSCR device,
One (1) 13,364 kilowatt (kW) Solar Titan 130 gas-fired turbine with SoLoNOx technology, and
Two (2) Caterpillar 3516 2,000 kW EPA certified emergency diesel generators.
The other permitted equipment bulleted below has not been installed nor operated in the first year of Facility
operation. These equipment are still referred to throughout the application, but are consistently mentioned to
not be in operation and the monitoring, recordkeeping, testing, and reporting included in the AO are not
conducted due to this equipment not existing at the Facility.
Two (2) 4 million standard cubic feet per day (MMSCFD) ethylene glycol (EG) dehydrators each with a
flash tank and 0.55 million British thermal units per hour (MMBtu/hr) reboiler,
Three (3) pressurized natural gas liquids (NGL) tanks,
Loadout points for NGLs, and
Fugitive leak emissions.
The following application follows the Appendix outline as indicated in the Operating Permit Application Form
and Checklist. The certification by a responsible official is included on the Operating Permit Application Form
and in Appendix L.
Should you have any questions or comments about the application, please contact Kaitlin Meszaros by email at
meszaros@pinyon-env.com or by phone at 631-245-0308. Thank you for your assistance in this matter.
Sincerely,
PINYON ENVIRONMENTAL, INC.,
Kaitlin A Meszaros
Air Quality Specialist
cc: Michael Duplantis, Crusoe Energy Systems Inc.
Laura Pritchard, Crusoe Energy Systems, Inc.
Brandy Cannon, Utah Division of Air Quality Operating Permits Section
June 6, 2024
Initial Title V Operating Permit Application
Crusoe Energy Systems, Inc.
Duchesne Data Center Power Station Duchesne
County, Utah
Pinyon Project No.:
1/19-1347-01
Prepared by:
___________________________
Kaitlin Meszaros
Reviewed by:
___________________________
Dustin Collins
June 6 , 2024
Initial Title V Operating Permit Application
Crusoe Energy Systems, Inc.
Duchesne Data Center Power Station Duchesne
County, Utah
Pinyon Project No.:
1/19-1347-01
Table of Contents
Operating Permit Application Completeness Checklist
Operating Permit Application Form
Appendix A – Site Plan
Appendix B – Process Flow Diagram
Appendix C – Process Description
Appendix D – Potential to Emit Emissions Calculations
Appendix E – Insignificant Emission Units
Appendix F – Air Pollution Control Equipment
Appendix G – Compliance Monitoring Devices & Test Methods
Appendix H – Regulatory Discussion
Appendix I – Exemptions NOT APPLICABLE
Appendix J – Emissions Trading NOT APPLICABLE
Appendix K – Compliance Plan and Schedule
Appendix L – Compliance Plan Certification
Operating Permit Application Completeness Checklist
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Comple Last revised June 29, 2000teness Checklist −1−
TO BE COMPLETED BY REVIEW ENGINEER WITHIN 60 DAYS OF RECEIPT OF THE APPLICATION. CRITERIA
DERIVED FROM R307-415-5, UTAH ADMINISTRATIVE CODE (UAC). ANY NEGATIVE RESPONSE WILL CAUSE
APPLICATION TO BE DEEMED ADMINISTRATIVELY INCOMPLETE IN ACCORDANCE WITH R307-415-5a(2), UAC.
ALL REFERENCES ARE TO THE UAC EXCEPT AS NOTED.
Source Identification Info1.rmation. [R307-415-5c(1)]
Name, address, and telephone number (w/area code) of:
A. Company submitting application. Y N
B. Plant manager and/or contact. Y N
C. Plant (if different from Company). Y N N/A
D. Company owner and agent. Y N
Comments:
Description of Source Process. [R307-415-5c(1)]2.
A. SIC Code(s) Y N
B. Description of processes involved: (Appendix C) Y N
C. Description of product(s): (Appendix C) Y N
Comments:
Emissions Related Information. [R307-415-5c(3)]3.
A. Is there other information available required by any applicable
requirement, such as: [R307-415-5c(3)(9)]
1. Location of emission units (Appendix A) Y N N/A
X
X
X
X
X
X
X
X
These data can be found in the Operating Permit Application Form
2A can be found in the Operating Permit Application Form. 2B & 2C can be found in Appendix C.
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −2−
2. Building dimensions (Appendix A) Y N N/A
3. Stack parameters (height, diameter, plume, temperature, etc.
(Appendix A)
Y N N/A
4. Flow rates (Appendix B) Y N N/A
B. Is information available on the following, to the extent it is needed, to
determine or regulate emissions: [R307-415-5c(3)(d)] (Appendix C)
1. Fuels Y N N/A
2. Fuel use Y N N/A
3. Raw material(s) Y N N/A
4. Production Rates Y N N/A
5. Operational schedule, including daily and seasonal variations,
associated with each emission unit.
Y N N/A
C. Does the application describe all potential emissions of air pollutants
for which the source is major? [R307-415-5c(3)(a)] (Appendix D)
Y N
D. Does the application describe all potential emissions for regulated
air pollutants? [R307-415-5c(3)(a)] (Appendix D)
Y N N/A
E. Does the application describe all potential emissions for hazardous
air pollutants? [R307-415-5c(3)(a)] (Appendix D)
Y N N/A
F. Does the application contain additional information related to the
emissions of air pollutants sufficient to verify which requirements are
applicable to the source and necessary to collect any permit fees?
[R307-415-5c(3)(a)] (Appendix D)
Y N
G. Does the application identify and describe all emission points in
sufficient detail to establish the basis for fees and applicability of
applicable requirements? [R307-415-5c(3)(b)] (Appendices A and
D)
Y N
X
X
X
X
X
X
X
X
X
X
X
X
X
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −3−
H. Are emission rates listed in units of tons per year and in such terms
as are necessary to establish compliance consistent with the
applicable standard reference test method? [R307-415-5c(3)(c)]
(Appendix D)
Y N
I. For regulated or hazardous air pollutants, are there any limitations on
source operations affecting: [R307-415-5c(3)(f)] (Appendix D)
1. Emissions Y N N/A
2. Any work practice standards Y N N/A
J. Does the application include calculations on which emissions-
related information are based? [R307-415-5c(3)(h)] (Appendix D)
Y N N/A
K. Is there a list of insignificant emissions units or activities exempted
from complete description because of size or production rate?
[R307-415-5c(3)(i)] (Appendix E)
Y N N/A
L. Does the application identify and describe control equipment ?
[R307-415-5c(3)(e)] (Appendix F)
Y N
Comments:
4. Monitoring Requirements.
A. Does the application identify and describe compliance monitoring
devices or activities? [R307-415-5c(3)(e)] (Appendix G)
Y N
B. Does the application contain a description of, or reference to, any
applicable test method for determining compliance with each
applicable requirement ? [R307-415-5c(4)(b)] (Appendix G)
Y N
Comments:
X
X
X
X
X
X
X
X
These data can be found in the Appendices listed in 3A through 3L.
These data can be found in the Appendix G. Note an explanation is provided on monitoring requirements that
are currently not carried out at the Facility due to the subject equipment not being installed or operational.
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −4−
5. Applicable Requirements.
A. Does the application cite and describe all applicable requirements,
to include but not limited to: SIP, HAP, NSPS, PSD, & NSR?
[R307-415-5c(4)(a)] (Appendix H)
Y N
B. Is other specific information that may be necessary to implement
and enforce applicable requirements or to determine the
applicability of such requirements included in the application?
[R307-415-5c(5)]
Y N N/A
C. Is there an explanation for any proposed exemptions from otherwise
applicable requirements? [R307-415-5c(6)] (Appendix I)
Y N N/A
Comments:
6. Other Information Requirements.
Is all additional information necessary to define the permit terms and
conditions for the following included in the application [R307-415-5c(7)]?
A. Alternative operating scenarios [R307-415-6a(9)] Y N N/A
B. Trading of emissions increases and decreases [R307-415-6a(10)]
(Appendix J)
Y N N/A
Comments:
7. Compliance Plan. (Appendix K)
Does the application include a compliance plan with all of the following:
A. Description of the compliance status of the source with respect to all
applicable requirements? [R307-415-5c(8)(a)]
Y N
X
X
X
X
X
X
5A can be found in Appendix H. Note an explanation is provided on requirements that are currently not
applicable to the Facility as the subject equipment has not been installed. Appendix I is not applicable.
These items are not applicable to this Facility.
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −5−
B. For applicable requirements with which the source is in compliance,
a statement that the source will continue to comply with such
requirements? [R307-415-5c(8)(b)(i)]
Y N N/A
C. For applicable requirements that will become effective during the
permit term, a statement that the source will meet such
requirements on a timely basis? [R307-415-5c(8)(b)(ii)]
Y N
D. For requirements for which the source is not in compliance at the
time of permit application, a narrative description of how the source
will achieve compliance with such requirements?
[R307-415-5c(8)(b)(iii)]
Y N N/A
Comments:
8. Compliance Schedule. (Appendix K)
Does the application include a compliance schedule which includes the
following:
A. For applicable requirements with which the source is in compliance,
a statement that the source will continue to comply with such
requirements ? [R307-415-5c(8)(c)(i)]
Y N N/A
B. For applicable requirements that will become effective during the
permit term, a statement that the source will meet such requirements
on a timely basis? [R307-415-5c(8)(c)(ii)]
Y N
C. A schedule of compliance for sources that are not in compliance with
all applicable requirements at the time of permit issuance which
includes the following: [R307-415-5c(8)(c)(iii)]
1. A schedule of remedial measures? Y N N/A
2. Enforceable sequence of actions with milestones leading to
compliance?
Y N N/A
X
X
X
X
X
X
X
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −6−
3. Resemble and at least as stringent as that contained in any
judicial consent decree or administrative order to which the
source is subject?
Y N N/A
D. Does the application include a schedule for submission of certified
progress reports no less frequently than every 6 months for sources
required to have a schedule of compliance to remedy a violation?
[R307-415-5c(8)(d)]
Y N N/A
E. If the source is an "affected source" under the acid rain portion of
the act, are the requirements of the compliance plan included in the
acid rain portion of a compliance plan for the source, except as
specifically superseded by regulations promulgated under title IV of
the Act? [R307-415-5c(8)(e)]
Y N N/A
Comments:
9. Certification of Compliance. (Appendix K)
A. Is there a certification of compliance with all applicable requirements
and the truth, accuracy, and completeness of the application based
on information and belief formed after reasonable inquiry, signed by
a responsible official? [R307-415-5c(9)(a)] (This is not the same
as the certification of the application! Two certifications are required
for the app to be complete.)
Y N
B. Does the application include a statement of the methods used for
determining compliance, to include the following:
[R307-415-5c(9)(b)]
1. description of monitoring? Y N N/A
2. recordkeeping? Y N N/A
3. reporting requirements? Y N N/A
4. test methods?
Y N N/A
X
X
X
X
X
X
X
X
There are no current conditions for which the Facility is in violation and therefore schedules to come into
compliance are not provided. The Facility is not an affected source under the Acid Rain Program.
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
COMPLETENESS CHECKLIST
Utah Operating Permit Application Completeness Checklist Last revised September 13, 2006 −7−
C. Does the application include a schedule for submission of
compliance certifications during the permit term, to be submitted
annually, or more frequently if specified by the underlying applicable
requirement or by the Executive Secretary? [R307-415-5c(9)(c)]
Y N
D. Does the application include a statement indicating the source's
compliance status with any applicable enhanced monitoring and
compliance certification requirements of the act?
[R307-415-5c(9)(d)]
Y N N/A
Comments:
10. Does the application use nationally-standardized forms for acid rain
portions of the application and compliance plan? [R307-415-5c(10)]
Y N N/A
11. Is the application form certified by a responsible official stating that
based on information and belief formed after reasonable inquiry, the
statements and information in the document are true, accurate, and
complete? [R307-415-5d]
Y N
X
X
X
X
Operating Permit Application Form
OPERATING PERMIT APPLICATION FORM October 19, 2006
Utah Division of Air Quality
OPERATING PERMIT APPLICATION
APPLICATION FOR: X INITIAL
MODIFICATION
RENEWAL
AN APPLICATION FOR A PERMIT TO OPERATE MUST BE SUBMITTED WITHIN 12 MONTHS OF COMMENCING
OPERATION OR OCTOBER 10, 1995, WHICHEVER IS LATER; OR, FOR RENEWALS, NOT LATER THAN THE
RENEWAL DATE. This is not a stand alone document. Please refer to the Utah Administrative Code or the Permit
Application Instructions for specific details required to complete the application. Please print or type all information requested.
A completeness review will be made utilizing a Completeness Checklist. If you would like a copy of the checklist or if you
have any questions please contact the Operating Permit Section of the Division of Air Quality at (801) 536-4000. Written
inquiries may be addressed to: Division of Air Quality, Operating Permit Section, P.O. Box 144820, Salt Lake City, Utah
84114-4820.
GENERAL OWNER AND PLANT INFORMATION
1. Company name and address:
Crusoe Energy Systems, Inc.
255 Fillmore Street
Denver, CO 80206
Phone: ( 970 ) 749-8615
FAX: N/A
2. Company contact for environmental issues:
Laura Pritchard
Environmental Specialist
lpritchard@crusoeenergy.com
Phone: ( 970 ) 749-8615
FAX: N/A
3. Plant name and address, and plant contact (if different
from above):
Duchesne Data Center Power Station (aka Snapper
Facility)
40.28899, -110.20166
Phone: same as above
FAX: same as above
4. Owner's name and address (if different from #1):
Same as #1
Phone: Same as #1
FAX: Same as #1
5. Is plant permanent? X Yes No If not, how long will equipment be at this location?
6. County plant is located in: _Duchesne_____________ Are you within 50 miles of state border? X Yes No
Border with Wyoming
7. Directions to plant (street address and/or directions to site to include U.S. Geological Survey
map if necessary): From Roosevelt, travel on US-191S/US-40W for 4.9 miles. Turn right onto UT-87S and
continue for 8.7 miles. Turn right onto S 8000 W and in 1.4 miles stay left to remain on S 8000 W. Turn left
onto Ledge Lane/1250 S and continue for 3.0 miles. Turn right onto 11000 W and continue on dirt road.
Facility entrance is on the left after 0.3 miles.
8. Identify any current Approval Order(s) (continue on separate sheet if necessary): Grandfathered? Yes X No
AO# DAQE-AN161210002-23_Date _02_/_13_/_2023___
9. If request for modification, previous operating permit # and date:
DAQO #__N/A__________________________ DATE: ____/____/____
10. Type of business at this plant: ___________________________________________________________________
11. Is your company a Small Business?
Yes X No
12. Standard Industrial Classification (SIC) Code
(See Instructions): [1] [3] [8] [9]
OPERATING PERMIT APPLICATION FORM October 19, 2006
PROCESS INFORMATION
13. Site plan of plant drawn to scale to include location of emission units (Attach as Appendix A):
14. Flow diagram of emission unit(s) at the plant to include flow rates and other applicable information (Attach as
Appendix B):
15. Detailed process/equipment description. (Attach as Appendix C)
Description must include:
X Process/Equipment specific form(s) identified in the instructions
X Fuels and their use X Equipment used in process X Description of product(s)
X Raw materials used X Operation schedules N/A Description of changes to process
X Production rates (include daily/seasonal variances) (if applicable)
16. Does this application contain confidential information? Yes X No
If yes, mark those portions claimed confidential and submit a statement in support of the claim.
17. Are you requesting that the permit include Alternative Operating Scenario(s)? Yes X No
If yes, include the detailed information described in this application for each alternative requested.
EMISSIONS RELATED INFORMATION
18. Describe all potential emissions of air pollutants. (Attach as Appendix D).
Include the following:
X Emissions for which the source is major.
X Emissions of regulated air pollutants.
X Emissions of hazardous air pollutants.
X Description of any operational constraints or work practices imposed that limit the amount of regulated or
hazardous air pollutants.
X Emissions above described in appropriate units (lbs/hr, lbs/day, ppm, etc.) based on the underlying standard,
and in tons/year.
X All calculations, including conversion factors as appropriate, to support the emissions data above.
19. Identify on the site plan (see #13 above) all emissions points; and all relevant building dimensions, stack
parameters, etc. Listed on additional pages rather than diagram.
20. List and describe any insignificant emission units. (Attach as Appendix E)
21. List all air pollution control equipment and include equipment specific forms identified in the instructions.
(Attach as Appendix F)
MONITORING INFORMATION
22. List and describe all compliance monitoring devices and activities. (Attach as Appendix G)
23. Cite and describe any applicable test methods used for determining compliance. (Include with Appendix G)
APPLICABLE REQUIREMENTS
24. Cite and describe all applicable requirements with regard to (but not limited to) the following (attach as
Appendix H):
X SIP X HAP X NSPS PSD X NSR UACR Title IV X Approval Order Other
25. Are there any proposed exemptions from applicable requirements? (If yes, attach as Appendix I) Yes X No
Appendix A – Site Plan
At the end of the Appendix is the site plan for the Crusoe Energy Systems, Inc. (Crusoe) Duchesne Data
Center Power Station commonly referred to operationally as the Snapper Facility. The facility coordinates are
40.28899 latitude north and -110.20166 longitude west in Duchesne County approximately eleven miles west
of Roosevelt, Utah. At this time, the permitted ethylene glycol (EG) dehydrators, associated reboilers, and
pressurized bullet tanks with loadout points are not installed and operational.
Included in Appendix A are tables detailed the emissions points in the site plan along with dimensions of the
onsite buildings and stack parameters. These parameters were built as demonstrated in the dispersion modeling
submitted with the initial Approval Order application.
Table A-1 Crusoe Emissions Points Sources
Source Description Location
(UTM Zone 12 meters)
TURBINE Titan 130 13,364 kilowatt turbine 567796.4, 4460080.0
GEN1 Waukesha 9394GSI 2,500 horsepower generator 567877.6, 4460113.9
GEN2 Waukesha 9394GSI 2,500 horsepower generator 567878.0, 4460095.0
GEN3 Waukesha 9394GSI 2,500 horsepower generator 567879, 4460077.4
GEN4 Waukesha 9394GSI 2,500 horsepower generator 567879.4, 4460059.7
GEN5 Waukesha 9394GSI 2,500 horsepower generator 567878.8, 4460040.4
GEN6 Waukesha 9394GSI 2,500 horsepower generator 567950.9, 4460113.9
GEN7 Waukesha 9394GSI 2,500 horsepower generator 567950.9, 4460095.0
GEN8 Waukesha 9394GSI 2,500 horsepower generator 567951.7, 4460077.2
GEN9 Waukesha 9394GSI 2,500 horsepower generator 567952.1, 4460058.5
GEN10 Waukesha 9394GSI 2,500 horsepower generator 567952.1, 4460040.8
BOOST1 Waukesha H24 530 horsepower compressor 567792.9, 4460065.4
BOOST2 Waukesha H24 530 horsepower compressor 567793.1, 4460048.0
EG1 & REB1 8 million cubic feet per day EG dehydrator with 0.55
million British thermal units per hour reboiler 567756.8, 4460041.5
EG2 & REB2 8 million cubic feet per day EG dehydrator with 0.55
million British thermal units per hour reboiler 567763.3, 4460047.5
EGEN1 CAT 3516 2,944 horsepower Tier IV emergency
generator 567878.8, 4460019.5
EGEN2 CAT 3516 2,944 horsepower Tier IV emergency
generator 567879.0, 4460011.2
Table A-2 Stack Parameters for Crusoe Sources
Source Source
Type
Stack
Height (ft)
Stack Diameter
(in)
Stack Flow
Rate (acfm)
Stack
Temp (oF)
TURBINE Point 40 72 258,260 918
GEN1 Point 25 13 10,270 1,091
GEN2 Point 25 13 10,270 1,091
GEN3 Point 25 13 10,270 1,091
GEN4 Point 25 13 10,270 1,091
GEN5 Point 25 13 10,270 1,091
GEN6 Point 25 13 10,270 1,091
GEN7 Point 25 13 10,270 1,091
GEN8 Point 25 13 10,270 1,091
GEN9 Point 25 13 10,270 1,091
GEN10 Point 25 13 10,270 1,091
BOOST1 Point 25 13 2,989 1,239
BOOST2 Point 25 13 2,989 1,239
EG1 & REB1 Point 18 12 942 350
EG2 & REB2 Point 18 12 942 350
EGEN1 Point 18 18 5,821 917
EGEN2 Point 18 18 5,821 917
Table A-3. Building Parameters
Building ID Building Description Shape Height
(feet)
Length
(feet)
Width
(feet)
Miner101 Miner box Rectangular 9.5 40 8
Miner103 Miner box Rectangular 9.5 40 8
Miner105 Miner box Rectangular 9.5 40 8
Miner109 Miner box Rectangular 9.5 40 8
Miner111 Miner box Rectangular 9.5 40 8
Miner119 Miner box Rectangular 9.5 40 8
Building ID Building Description Shape Height
(feet)
Length
(feet)
Width
(feet)
Miner113 Miner box Rectangular 9.5 40 8
Miner115 Miner box Rectangular 9.5 40 8
Miner117 Miner box Rectangular 9.5 40 8
Miner118 Miner box Rectangular 9.5 40 8
Miner116 Miner box Rectangular 9.5 40 8
Miner114 Miner box Rectangular 9.5 40 8
Miner120 Miner box Rectangular 9.5 40 8
Miner108 Miner box Rectangular 9.5 40 8
Miner107 Miner box Rectangular 9.5 40 8
Miner106 Miner box Rectangular 9.5 40 8
Miner104 Miner box Rectangular 9.5 40 8
Miner102 Miner box Rectangular 9.5 40 8
Miner220 Miner box Rectangular 9.5 40 8
Miner218 Miner box Rectangular 9.5 40 8
Miner214 Miner box Rectangular 9.5 40 8
Miner212 Miner box Rectangular 9.5 40 8
Miner210 Miner box Rectangular 9.5 40 8
Miner214 Miner box Rectangular 9.5 40 8
Miner208 Miner box Rectangular 9.5 40 8
Miner206 Miner box Rectangular 9.5 40 8
Miner204 Miner box Rectangular 9.5 40 8
Miner202 Miner box Rectangular 9.5 40 8
Miner201 Miner box Rectangular 9.5 40 8
Miner203 Miner box Rectangular 9.5 40 8
Miner205 Miner box Rectangular 9.5 40 8
Miner207 Miner box Rectangular 9.5 40 8
Miner209 Miner box Rectangular 9.5 40 8
Building ID Building Description Shape Height
(feet)
Length
(feet)
Width
(feet)
Miner211 Miner box Rectangular 9.5 40 8
Miner213 Miner box Rectangular 9.5 40 8
Miner215 Miner box Rectangular 9.5 40 8
Miner217 Miner box Rectangular 9.5 40 8
Miner219 Miner box Rectangular 9.5 40 8
M/V MCC Controls building Rectangular 10 35 6
L/V MCC Controls building Rectangular 13 22 16
TURBINE Turbine building Rectangular 20 82 20
GEN1 Generator building Rectangular 20 40 20
GEN2 Generator building Rectangular 20 40 20
GEN3 Generator building Rectangular 20 40 20
GEN4 Generator building Rectangular 20 40 20
GEN5 Generator building Rectangular 20 40 20
GEN6 Generator building Rectangular 20 40 20
GEN7 Generator building Rectangular 20 40 20
GEN8 Generator building Rectangular 20 40 20
GEN9 Generator building Rectangular 20 40 20
GEN10 Generator building Rectangular 20 40 20
BOOST1 Compressor building Rectangular 18 35 18
BOOST2 Compressor building Rectangular 18 35 18
EGEN1 Emergency Generator building Rectangular 15.5 58.5 11.33
EGEN2 Emergency Generator building Rectangular 15.5 58.5 11.33
TANK1 Natural gas liquids bullet tank Rectangular 5 33 5
TANK2 Natural gas liquids bullet tank Rectangular 5 33 5
TANK3 Natural gas liquids bullet tank Rectangular 5 33 5
I/A Skid Instrument Air building Rectangular 9 7 7
CrusoeEnergySitePlan
Snapper Facility
N
800’
400’
100’
SCALE
AccessRoad
80’
200’
55’55’75’
50’
75’
Appendix B – Process Flow Diagram
On the following page, the plot plan has been modified to show the process flow for the facility. A narrative of
the process flow is included in Appendix C. At this time, the gas sold to Crusoe is a quality suitable for
consumption by the turbine, compressor engines, and generator engines without additional processing.
Therefore, the permitted ethylene glycol (EG) dehydrators, associated reboilers, and pressurized bullet tanks
with loadout points are not installed and operational.
Based on the installed equipment at the facility, Crusoe may consume up to 6 million standard cubic feet per
gas per day (MMSCFD). The breakdown for that consumption is indicated below:
Turbine – 2.8 MMSCFD
Compressor Engines – 0.1 MMSCFD each
Generator Engines – 0.3 MMSCFD each
In the event of an unexpected or emergency facility shutdown, the two emergency generators may be utilized.
Their consumption is limited by the number of runtime hours. At this time, the emergency diesel generator
engines have not operated.
Emergency Diesel Generator Engines – 275.2 gallons per hour each
Emergency Diesel Generator Engines – 500 hours per year (includes run-time for emergency use)
As mentioned, the EG dehydrators, associated reboilers, and NGL bullet tanks have not been necessary for
the facility and have not been installed. Their permitted flow rates are below.
EG Dehydrators – 4 MMSCFD each
EG Reboilers – 0.01 MMSCFD each
NGL Bullet Tanks – approximately 8,000 gallons per day (combined maximum)
Crusoe Energy
Flow Diagram
Snapper Facility
As-Built
N
800’
400’
100’
SCALE
Access Road
80’
55’55’75’Gas
50’
75’
At time of submittal, the EG dehydrators, reboilers,
and bullet tanks with associated leaks are not installed
Electricity
EG1 & REB1
EG2 & REB2
EGEN1
EGEN2
Inlet Custody Meter
Appendix C – Process Description
Equipment used in process
Crusoe Energy Systems (Crusoe) permitted the following equipment at the Duchesne Data Center Power
Station and is approved under DAQE-AN16120002-23:
Two (2) 530 horsepower (hp) Waukesha VGF H24SE compressor engines each fitted with a non-selective
catalytic reduction (NSCR) device,
Ten (10) 2,500 hp Waukesha 9394GSI generator engines each fitted with a NSCR device,
One (1) 13,364 kilowatt (kW) Solar Titan 130 gas-fired turbine with SoLoNox technology,
Two (2) Caterpillar 3516 2,000 kW certified emergency diesel generators,
Two (2) 4 million standard cubic feet per day (MMSCFD) ethylene glycol dehydrators each with a flash
tank and 0.55 million British thermal units per hour (MMBtu/hr) reboiler, (NOT INSTALLED)
Three (3) pressurized natural gas liquids (NGL) tanks, (NOT INSTALLED)
Loadout points for NGLs, and (NOT INSTALLED)
Fugitive leak emissions. (NOT INSTALLED)
The purpose of the equipment is to take gas from the adjacent XCL Facility to the north that would otherwise
be flared to use as fuel in order to power small data centers.
Permitted Process Description:
Stranded gas from the Facility will first be routed to the Waukesha VGF H24SE compressor engines to increase
pressure of the gas prior to the mechanical refrigeration unit (MRU). The MRU will strip out NGLs creating a
leaner gas to be fed to the turbine. Part of the MRU process is the EG dehydration units to remove water from
the fluid stream. Gas volume that the turbine cannot handle decreases pressure to provide fuel to the
Waukeshas generators. It is also practical to run the Waukesha generators directly on unprocessed gas when
the fuel gas compressors and/or MRU processing is not available. The generators and turbine use the fuel to
generate electricity for small data centers that will also be onsite. The NGLs are stored in pressurized storage
tanks before being loaded offsite.
The use of the two (2) 2,000 kW certified diesel generators would be to power the data centers should the
compressor engines, generator engines, turbine, and dehydrators go down and loss of utility electric power.
Use of the emergency generators is not expected to be more than 500 hours per year. There is no circumstance
in which the other equipment at the facility will operate at the same time as the diesel generators. To
demonstrate this, the emissions inventory is presented in two scenarios: the normal operating scenario where
the full facility runs 8,760 hours per year and the emergency operating scenario where the full facility runs
8,260 hours per year and the emergency diesel generators run for 500 hours per year.
As-Built Process Description:
Stranded gas from the Facility will first be routed to the Waukesha VGF H24SE compressor engines to increase
pressure of the gas prior to the turbine. Gas volume that the turbine cannot handle decreases pressure to
provide fuel to the Waukeshas generators. It is also practical to run the Waukesha generators directly on
unprocessed gas when the fuel gas compressors are not available. The generators and turbine use the fuel to
generate electricity for small data centers that will also be onsite.
The use of the two (2) 2,000 kW certified diesel generators would be to power the data centers should the
compressor engines, generator engines, and turbine go down and loss of utility electric power. Use of the
emergency generators is not expected to be more than 500 hours per year. There is no circumstance in which
the other equipment at the facility will operate at the same time as the diesel generators.
Fuels and their use
The Facility is expected to consume approximately 6 MMSCFD of field gas per day. The estimated heat content
of the field gas is between 1,300 and 1,400 British thermal units per standard cubic feet (Btu/scf). No more
than 25 ppm hydrogen sulfide (H2S) is expected in the field gas. The breakdown by equipment is below.
Turbine – 2.8 MMSCFD of field gas
Compressor Engines – 0.1 MMSCFD of field gas each
Generator Engines – 0.3 MMSCFD of field gas each
Emergency Diesel Generator Engines – 137,600 gallons of ultra-low sulfur diesel per year each
EG Reboilers – 0.01 MMSCFD of field gas each (NOT INSTALLED)
Raw materials used
The facility does not use any raw materials.
Production rates & description of products
The Facility through its process will produce electricity. Below are the maximum electricity generation by
equipment.
Turbine – 13.364 megawatt-hours (MWh) and 117,070 MW per year
Generator Engines – 2 MWh and 17,520 MW per year each
Emergency Diesel Generator Engines – maximum of 2 MWh and 1,000 MW per year each
No changes to the process are expected.
Operation Schedules
The turbine, compressor engines, and generator engines are expected to run 24 hours per day, 7 days per
week, and 365 days per year. In unpredicted and emergency events where these equipment are not operational,
the emergency diesel generators will become operational. It is expected the two emergency generators will
not operate more than 500 hours per year in emergency events.
The following pages include the process/equipment specific forms for the equipment bulleted at the beginning
of this Appendix.
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day______ Hours/day
Days/week Days/week
______ Weeks/year______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
Proposed site operating range _____________________________ hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: □ Yes □ No
5. Are you on an interruptible gas supply:
□ Yes □ No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ BTU/hr
Oil Firing
9. Type of oil:
Grade number □ 1 □ 2 □ 4 □ 5 □Other specify ___________6
10. Annual consumption: ______________ gallons
11. Heat content:______________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight
13. Ash content: ____________% by weight
14. Average firing rate: gal/hr
15. Maximum firing rate: gal/hr
16. Direction of firing: □ horizontal □ tangential □ other: (specify)
Page 1 of 4
Waukesha
VGF H24SE
2022
24
7
52
24
7
52
1,060 (total)
1,060 (total)
67.03
10,279,880 10,279,880
Crusoe Energy Systems, Inc.
Snapper Facility/BOOST1 & BOOST2
6/6/2024
Page 2 of 4
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□ Electric generation
______ Base load ______ Peaking
□ Emergency Generator
□ Driving pump/compressor
□ Exhaust heat recovery
□ Other (specify) ________________________
18. Cycle
□ Simple cycle
□ Regenerative cycle
□ Cogeneration
□ Combined cycle
Emissions Data
19. Manufacturer’s Emissions in grams per hour (gr/hp-hr): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N 2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□ Lean premix combustors □ Oxidation catalyst □ Water injection □ Other (specify)____________
□ Other low-NOx combustor □ SCR catalyst □ Steam injection
Additional Information
21. On separate sheets provide the following:
A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
C. All calculations used for the annual emission estimates must be submitted with this form to be deemed
complete.
D. All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using
SCREEN3.
E. If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Fuel Gas Booster Compression
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Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
Proposed site operating range _____________________________ hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: □ Yes □ No
5. Are you on an interruptible gas supply:
□ Yes □ No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ BTU/hr
Oil Firing
9. Type of oil:
Grade number □ 1 □ 2 □ 4 □ 5 □ 6 Other specify ___________
10. Annual consumption: ______________ gallons
11. Heat content:______________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight
13. Ash content: ____________% by weight
14. Average firing rate: gal/hr
15. Maximum firing rate: gal/hr
16. Direction of firing: □ horizontal □ tangential □ other: (specify)
Page 1 of 4
Crusoe Energy Systems, Inc.
GEN1 through GEN10
6/6/2024
Waukesha
9394 GSI 24
7
52
24
7
52
25,000 (total)
25,000 (total)
1,387
212,695,750 212,695,750
2022
Page 2 of 4
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□ Electric generation
______ Base load ______ Peaking
□ Emergency Generator
□ Driving pump/compressor
□ Exhaust heat recovery
□ Other (specify) ________________________
18. Cycle
□ Simple cycle
□ Regenerative cycle
□ Cogeneration
□ Combined cycle
Emissions Data
19. Manufacturer’s Emissions in grams per hour (gr/hp-hr): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N 2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□ Lean premix combustors □ Oxidation catalyst □ Water injection □ Other (specify)____________
□ Other low-NOx combustor □ SCR catalyst □ Steam injection
Additional Information
21. On separate sheets provide the following:
A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
C. All calculations used for the annual emission estimates must be submitted with this form to be deemed
complete.
D. All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using
SCREEN3.
E. If this form is filled out for a new source, forms 1 and 2 must be submitted also.
0.15 0.30 0.03
0.001
100%
Page 4 of 4
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE
EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Please refer to Appendix A
Utah Division of Air Quality
New Source Review Section Company____________________
Site/Source___________________
Form 22 Date________________________
Combustion Turbines
Equipment Information
1. Manufacturer: ______________________________
Model Number: ______________________________
2. Operating time of Emission Source:
AVERAGE MAXIMUM
Hours/day _________ _________
Days/week _________ _________
Weeks/year _________ _________
4. Percent of annual heat input:
Dec-Feb _____% Mar-May _____% Sep-Nov _____%Jun-Aug _____%
Gas Firing
5. Origin of gas:
□ Pipeline □ Distillate fuel □ Other liquid □ Solid fuel □ Byproduct, specify source: ______
oil gasification fuel gas ___________________________ification gasification ___
6. Are you on an interruptible gas supply:
□ Yes □ No
If "yes", specify alternate fuel:
________________________________
7. Annual consumption of fuel: _______________ scf
*8. Heat content: _________________________ BTU/scf *9. Sulfur content: ________________________ % by wt.
10. Maximum firing rate: ____________________ scf/hr 11. Average firing rate: ____________________ scf/hr
*If the gas fired is pipeline grade natural gas, these items need not be completed.
Oil Fired
12. Grade of oil, Number: □ 1 □ 2 □ 4 □ 5 □ 6 □ Other: specify ___________________________
13. Annual consumption: ___________________ gallons 14. Heat content: ____________________ □ BTU/lb
□ BTU/gal
15. Sulfur content: _____________________ % by wt. 16. Ash content _________________________ % by wt.
17. Direction of firing: □ horizontal □ tangential □ other: specify ________________________________
18. Average firing rate: ______________________ gal/hr 19. Maximum firing rate: _____________________ gal/hr
Page 1 of 3
Crusoe Energy Ststems, Inc.
Snapper Facility/TURBINE
6/6/2024
Solar
Titan 130 24
7
52
24
7
52
868,244,428
1,343 0.0025
99,115 99,115
25 25 25 25
3. Manufacturer's rated output at baseload, ISO: ___1__3.364 _ □ MW or □ hp
Proposed site operating range: ___________1 _3 _ _3 _6 _4 _________ ____ □ MW or □ hp
Manufacturer's rated heat rate at baseload, ISO: _____ _9,__7 _6 _6 _______ (BTU/kW-hr)
.
Form 22 – Combustion Turbines
Operation
20. Application: □ Electric generation
____Base load ____Peaking
□ Driving pump/compressor
□ Exhaust heat recovery
□ Other – Specify ________________
21. Cycle: □ Simple cycle
□ Regenerative cycle
□ Cogeneration
□ Combined cycle
22. Is turbine equipped with exhaust heat recovery equipment? □ Yes □ No
If yes, supply the size, flow rate, steam output capacity and temperature profile.
23. Is turbine equipped with duct burners? □ Yes □ No
If yes, provide burner description, fuel usage, combustion air input and location of the burners. Show all heat transfer
surface locations with the waste heat boiler and temperature profile.
Emissions Data
24. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, PM10 and PM2.5 for each proposed fuel at
turbine loads and site ambient temperatures representative of the range of proposed operation. The information must
be sufficient to determine maximum hourly and annual emission rates. Annual emissions may be based on a
conservatively low approximation of site annual average temperature. Provide emissions in pounds per hour and
except for PM10 and PM2.5, parts per million by volume at actual conditions and corrected to dry, 15% oxygen conditions.
Method of Emission Control:
□ Lean premix combustors □ Oxidation catalyst □ Water injection □ Other – Specify ____________
□ Other low-NOx combustor □ SCR catalyst □ Steam injection ________________________
Additional Information
25. On separate sheets provide the following:
A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus turbine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
Emissions Calculations (PTE)
26. Calculated emissions for this device
PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr
NOx ___________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr
CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr
CO2 ___________Tons/yr CH4 ___________Tons/yr
N2O ___________Tons/yr
HAPs__________ Lbs/hr (speciate)___________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
Page 2 of 3
SoLoNOx
0.88 0.883.85 3.85
13.33 58.37 0.42 1.83
4.65 20.35
1.29
8.11 35.53
68,232
0.13
0.14 0.60
1. See emissions calculation spreadsheet for
speciated HAPs
100%
Utah Division of Air Quality
New Source Review Section Company: ___________________
Site/Source: _________________
Form 17 Date: _____________________
Diesel Powered Standby Generator
Company Information
1. Company Name and Address:
____________________________________________
____________________________________________
____________________________________________
____________________________________________
Phone Number: _______________________________
Fax Number: _______________________________
2. Company Contact:
____________________________________________
____________________________________________
____________________________________________
____________________________________________
Phone Number: _______________________________
Fax Number: _______________________________
3. Installation Address:
____________________________________________ County where facility is located: __________________
____________________________________________
____________________________________________ Latitude, Longitude and UTM Coordinates of Facility
____________________________________________ __________________________________________
Phone Number: _______________________________ __________________________________________
Fax Number: _______________________________
Standby Generator Information
4. Engines:
Maximum Maximum Emission Rate Date the engine
Manufacturer Model Rated Hours of Rate of NO x was constructed
5. Calculated emissions for this equipment:
PM10 ____________ Lbs/hr _____________Tons/yr PM2.5____________ Lbs/hr _____________Tons/yr
NOx_____________Lbs/hr______________Tons/yr SO x ____________ Lbs/hr______________Tons/yr
CO _____________Lbs/hr______________Tons/yr VOC ____________Lbs/hr______________Tons/yr
CO2 ____________Tons/yr CH4 ____________ Tons/yr
N2O ____________Tons/yr
HAPs___________ Lbs/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
Crusoe Energy Systems, Inc.
255 Fillmore Street
Denver, CO 80206
Laura Pritchard
970-749-8615
40.28899, -110.20166
N/A - see coordinate location
567,859 E, 4,460,140 N
Duchesne
0.13 0.032 0.13 0.013
4.93 1.23 0.057 0.014
1.30
1,537.5
0.0125
0.051 0.013
0.32 0.13 0.03
0.062
1. See emissions calculation spreadsheet for
speciated HAPs
Crusoe Energy Systems, Inc.
Snapper Facility/ EGEN1 & EGEN2
6/6/2024
Horsepower or Kilowatts Operation grams/BHP-HR or reconstructed
____C _at __er _p_il _l _a _r _______3 _5 _1 _6 ____________5,__8 _82 (total)_hp_____________5 _0 _0 ______________0_._3 _8______________2 _0 _2 _2 ______
_______________________________________________________________________________________________
___*_E __m _i _s _si _o __n _s _t _o _t _al _s _ _a _r _e _ f __or _ _E __U _0 _4 _ _(_2 _x _ __C _at __er _p_il_l _a _r __3 _5 _1 _6 _ _D _i _e _s _e _l __E _n _g _i _n _e _s _)____________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
_______________________________________________________________________________________________
Attach Manufacturer-supplied information
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:
2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□ Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □ No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□ Batch
□ Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials
Principal Use
Amounts
(Specify Units)
Page 1 of 3
Crusoe Energy Systems, Inc.
Snapper Facility / EG Dehydration
6/6/2024
EG Dehydration -
2 x EG Dehydrators
N/A
N/A
N/A
N/A
N/A
N/A
N/A N/A
24
7
52
25
25 25
25
Dehydrator Still Vent
N/A N/A
N/A
N/A
stranded gas 8.00 MMscf/d remove NGLs (total)
NOT INSTALLED - associated with natural gas
processing plant
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item
Primary Collector
Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:
14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□ Yes □ No
If yes, identify sources:
16. □ Round, top inside diameter dimension
_________
□ Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________ oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A
N/A - vent release point
--
--
--
-
-
--
-
11.43 1.14
2.86
0.087 See emissions calculations for
speciated HAPs0.020
0.65
Utah Division of Air Quality
New Source Review Section Company _______________________
Site/Source _____________________
Form 19 Date ___________________________
Natural Gas Boilers and Liquid Heaters
Boiler Information
1. Boiler Manufacturer: ___________________________________________________________________________
2. Model Number: ______________________________ 3. Serial Number: _______________________________
4. Boiler Rating: _________________(106 Btu per Hour)
5. Operating Schedule: __________ hours per day __________ days per week ___________ weeks per year
6. Use: □ steam: psig □ hot water □ other hot liquid: ________________________________
□ Natural Gas □ LPG □ Butane □ Methanol
□ Process Gas - H2S content in process gas __________ grain/100cu.ft.
7. Fuels:
□ Fuel Oil - specify grade: □ Other, specify: ______________________________________
Sulfur content % by weight Days per year during which unit is oil fired: ________________
Backup
Fuel □ Diesel □ Natural Gas □ LPG □ Butane □ Methanol □ Other _________________
8. Is unit used to incinerate waste gas liquid stream? □ yes □ no
(Submit drawing of method of waste stream introduction to burners)
Gas Burner Information
9. Gas Burner Manufacturer: _____________________________________________________________________
10. No. of Burners: ______________________________ 11. Minimum rating per burner: _____________ cu. ft/hr
12. Average Load: _______% 13. Maximum rating per burner: ____________ cu. ft/hr
14. Performance Guarantee (ppm dry corrected to 3% Oxygen):
NOx: ______________ CO: ______________ Hydrocarbons: ______________
□ Manual □ Automatic on-off 15. Gas burner mode of control:
□ Automatic hi-low □ Automatic full modulation
Oil Burner Information
16. Oil burner manufacturer:
17. Model: _______________ number of burners: _________________ Size number: _______________
18. Minimum rating per burner: _____________ gal/hr 19. Maximum rating per burner: ___________ gal/hr
Page 1 of 3
TBD
TBD TBD
Crusoe Energy Systems, Inc.
Snapper Facility / Dehydrator Reboilers
6/6/2024
0.55 (each)
24 7 52
NOT INSTALLED - associated with natural gas
processing plant
Page 2 of 3
Form 11 - Natural Gas Boiler and Liquid Heater
(Continued)
Modifications for Emissions Reduction
20. Type of modification: □ Low NOX Burner □ Flue Gas Recirculation (FGR)
□ Oxygen Trim □ Other (specify) ______________________________________
For Low-NOX Burners
21. Burner Type: □ Staged air □ Staged fuel □ Internal flue gas recirculation
□ Ceramic □ Other (specify): ___________________________________________________
22. Manufacturer and Model Number: _______________________________________________________________
23. Rating: ______________________ 106 BTU/HR 24. Combustion air blower horsepower: ____________
For Flue Gas Recirculation (FGR)
25. Type: □ Induced □ Forced Recirculation fan horsepower: ______________________________________
26. FGR capacity at full load: scfm %FGR
27. FGR gas temperature or load at which FGR commences: OF % load
28. Where is recirculation flue gas reintroduced? _______________________________________________________
For Oxygen Trim Systems
29. Manufacturer and Model Number: ________________________________________________________________
30. Recorder: □ yes □ no Describe: ____________________________________________________________
Stack or Vent Data
31. Inside stack diameter or dimensions ____________
Stack height above the ground ________________
Stack height above the building ________________
32. Gas exit temperature: ___________ OF
33. Stack serves: □ this equipment only, □ other equipment (submit type and rating of all other equipment
exhausted through this stack or vent)
34. Stack flow rate: _________________ acfm Vertically restricted? □ Yes □ No
Emissions Calculations (PTE)
35. Calculated emissions for this device
PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr
NOx ___________Lbs/hr ___________Tons/yr SOx ____________Lbs/hr___________ Tons/yr
CO ____________Lbs/hr ___________Tons/yr VOC ___________Lbs/hr ___________Tons/yr
CO2 ___________ Tons/yr CH4 ___________Tons/yr
N2O ___________Tons/yr
HAPs_________ Lbs/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
1 ft (each)
18 ft (each)
973 (each)
N/A
943 (each)
0.054 0.24
0.0041 0.00410.018 0.018
0.00032 0.0014
0.0030 0.013
0.0053282.5
-
-
-
0.0010 0.0044 See emissions calculations for
speciated HAPs
emissions below are for a single dehydrator reboiler
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:
2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□ Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □ No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□ Batch
□ Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials
Principal Use
Amounts
(Specify Units)
Page 1 of 3
Crusoe Energy Systems, Inc.
Snapper Facility/ NGL Truck Loading
6/6/2024
NGL Truck Loading N/A
N/A
N/A
N/A
N/A
N/A
N/A N/A
1
7
52
N/A
N/A N/A
N/A
fugitive release point
N/A N/A
N/A
N/A
N/A N/A N/A
NOT INSTALLED - associated with natural gas
processing plant
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item
Primary Collector
Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:
14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□ Yes □ No
If yes, identify sources:
16. □ Round, top inside diameter dimension
_________
□ Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________ oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A
N/A - fugitive release
point
-
--
--
--
-
-
--
-
0.016 0.20
2.67
0.37-See emissions calculations for
speciated HAPs
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:
2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□ Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □ No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□ Batch
□ Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
Materials used in process11.
Raw Materials
Principal Use
Amounts
(Specify Units)
Page 1 of 3
Crusoe Energy Systems, Inc.
Snapper Facility / Fugitive Emissions
6/6/2024
Component Fugitive
Emissions
N/A
N/A
N/A
N/A
N/A
N/A
N/A N/A
intermittent
N/A
N/A N/A
N/A
fugitive release point(s)
N/A N/A
N/A
N/A
N/A N/A N/A
N/A
N/A
N/A
NOT INSTALLED - associated with natural gas
processing plant
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item
Primary Collector
Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:
14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□ Yes □ No
If yes, identify sources:
16. □ Round, top inside diameter dimension
_________
□ Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________ oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A
N/A - fugitive release
point(s)
--
--
--
-
-
--
-
0.023 0.72
0.40
0.038 See emissions calculations for
speciated HAPs
0.092
0.0087
Appendix D – Potential to Emit Emissions Calculations
Emissions for which the site is major
The Facility has potential emissions above 100 tons per year (ton/yr) for the following pollutants:
Carbon monoxide (CO) – 111.4 ton/yr
Emissions of regulated air pollutants & operational constraints
The Facility has the following potential emissions of regulated air pollutants. Note that the totals for the EG
dehydrators, associated reboilers, NGL bullet tanks, and fugitive emissions are included below, however are
not installed or operational at the Facility. A summary of the calculations is included at the end of this appendix.
Carbon monoxide (CO) – 111.4 ton/yr
Nitrogen oxides (NOx) – 96.59 ton/yr
Particulate matter with a diameter less than 10 microns (PM10) – 7.17 ton/yr
Particulate matter with a diameter less than 2.5 microns (PM2.5) – 7.17 ton/yr
Sulfur dioxide (SO2) – 4.88 ton/yr
Volatile organic compounds (VOC) – 36.61 ton/yr
The compressor engines and generator engines are each fitted with non-selective catalytic reduction (NSCR)
and in order to achieve and demonstrate the controlled emissions output, regular maintenance, monitoring,
and testing is required. The turbine is manufactured with low NOx control (SoLoNOx). Similarly, regular
maintenance, monitoring, and testing is required to achieve and demonstrate the controlled emissions output.
The emergency diesel generator engines were purchased certified to Tier 4 emissions standards. Only ultra-
low sulfur diesel (ULSD) will be used in the engines to minimize SO2 emissions. No other operational
constraints or work practices are enforced at the Facility as no other equipment is currently operational.
Emissions of hazardous air pollutants & operational constraints
The Facility has the following potential emissions of hazardous air pollutants (HAPs) in both pounds per hour
(lb/hr) and ton/yr. Note that the totals for the EG dehydrators, associated reboilers, NGL bullet tanks, and
fugitive emissions are included below, however are not installed or operational at the Facility. A summary of
the calculations is included at the end of this appendix.
Total HAPs – 10.47 ton/yr
Acetaldehyde – 0.48 lb/hr and 2.12 ton/yr
Acrolein – 0.45 lb/hr and 1.98 ton/yr
Benzene – 0.34 lb/hr and 1.48 ton/yr
Ethylbenzene – 0.01 lb/hr and 0.05 ton/yr
Formaldehyde – 0.15 lb/hr and 0.67 ton/yr
Methanol – 0.52 lb/hr and 2.30 ton/yr
Toluene – 0.12 lb/hr and 0.53 ton/yr
Xylenes – 0.04 lb/hr and 0.19 ton/yr
The compressor engines and generator engines are each fitted with non-selective catalytic reduction (NSCR)
and in order to achieve and demonstrate the controlled emissions output, regular maintenance, monitoring,
and testing is required. Neither the SoLoNOx control on the turbine nor the Tier 4 certification of the
emergency diesel generator engines have the ability to control HAPs. No other operational constraints or
work practices are enforced at the facility as no other equipment is currently operational.
Common conversions
1 lb = 453.59 grams (g)
1 kilogram (kg) = 1000 g
1 ton = 2000 lb
1 kg = 2.205 lb
1 yr = 8760 hr
1 day = 24 hr
Emissions Data Sources
Compressor Engines (BOOST1 & BOOST2)
Each engine is built with a NSCR device. The emission factors used to calculate emissions from the engines are
provided in AP-42 Chapter 3.2-3 and the following manufacturer specifications:
NOx: 0.15 g/hp-hr
CO: 0.30 g/hp-hr
VOC: 0.019 g/hp-hr
Formaldehyde: 0.001 g/hp-hr
Hazardous air pollutants (HAPs) that are also VOCs are reduced by the same efficiency as the VOCs. This is
footnoted in the emissions calculations.
Generator Engines (GEN1 through GEN10)
Each engine is built with a NSCR device. The emission factors used to calculate emissions from the engines are
provided in AP-42 Chapter 3.2, Table 3.2-3, and the following manufacturer specifications:
NOx: 0.15 g/hp-hr
CO: 0.30 g/hp-hr
VOC: 0.030 g/hp-hr
PM10/PM2.5: 0.010 g/hp-hr
Formaldehyde: 0.001 g/hp-hr
Hazardous air pollutants (HAPs) that are also VOCs are reduced by the same efficiency as the VOCs. This is
footnoted in the emissions calculations.
Turbine (TURBINE)
The turbine is built to minimize combustion emissions through the use of SoLoNOx dry low emissions (DLE)
technology. The emission factors used to calculate emissions from the turbine are based on manufacturer
specifications.
NOx: 25 ppm at 15% O2 (0.33 g/hp-hr)
CO: 25 ppm at 15% O2 (0.20 g/hp-hr)
HC: 25 ppm at 15% O2 assuming VOC is 100% of HC (0.12 g/hp-hr)
Emergency Generator Engines (EGEN1 & EGEN2)
Each diesel generator is certified to meet Tier 4 EPA certification for emergency use. The emission factors
used to calculate emissions from the emergency diesel generators are based on manufacturer data.
NOx: 0.38 g/hp-hr
CO: 0.10 g/hp-hr
VOC: 0.01 g/hp-hr
PM10/PM2.5: 0.01 g/hp-hr
EG Dehydrators and Reboilers (EG1 & EG2 with REB1 and REB2)
These emission units are not installed. The following narrative is based on the permitted process should they
be installed and operational: Flash tank gas will be recycled. There will be no controls on the still vent. Emissions
were calculated using GRI-GLYCalc 4.0 using an estimated wet gas analysis and maximum operating parameters
for the EG units. There will be no controls associated with the reboilers. Emissions are calculated using AP-42
Section 1.4 for natural gas external combustion units.
Natural Gas Liquid (NGL) Loading
This source is not installed. The following narrative is based on the permitted process should they be installed
and operational: NGLs will be stored under pressure until loadout. Therefore, NGL storage will not result in
emissions to the atmosphere. Emissions from NGL loadout are based on truck loadout vent line design and
estimated liquid composition output from GRI-GLYCalc 4.0.
Component Fugitive Emissions
This source is not installed. The following narrative is based on the permitted process should they be installed
and operational: The Facility will implement a fugitive leak detection and repair program per NSPS OOOOa.
Therefore, the emission factors for a leak detection threshold of 10,000 parts per million by volume were used.
NOx CO VOC SO2 PM/PM10/PM2.5 HAPs CO2e
ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr
Engines
2 x Waukesha VGF H24SE 143.8 94.17 2.05 0.14 0.87 1.05 5,273
10 x Waukesha 9394GSI 2,998 1,417 29.93 2.91 2.41 23.17 109,108
Turbine
1 x Titan 130 58.37 35.53 20.35 1.82 3.85 0.60 68,303
Dehydrators
TEG Dehydrator 1 - - 8.31 - - 0.19 233.2
TEG Dehydrator 2 - - 8.31 - - 0.19 233.2
Reboiler 1 0.24 0.20 0.013 0.0014 0.018 0.0044 282.8
Reboiler 2 0.24 0.20 0.013 0.0014 0.018 0.0044 282.8
NGL Loading
Truck Loadout - - 2.67 - - 0.37 5.01
Fugitive Emissions
Component Leak Emissions - - 0.40 - - 0.038 18.05
Total Facility PTE = 3,201 1,547 72.05 4.88 7.17 25.62 183,739
NOx CO VOC SO2 PM/PM10/PM2.5 HAPs CO2e
ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr
Engines
2 x Waukesha VGF H24SE 1.54 3.07 0.19 0.14 0.87 0.55 5,273
10 x Waukesha 9394GSI 36.21 72.42 7.24 2.91 2.41 8.74 109,108
Turbine
1 x Titan 130 58.37 35.53 20.35 1.82 3.85 0.60 68,303
Dehydrators
TEG Dehydrator 1 - - 2.86 - - 0.087 39.99
TEG Dehydrator 2 - - 2.86 - - 0.087 39.99
Reboiler 1 0.24 0.20 0.013 0.0014 0.018 0.0044 282.8
Reboiler 2 0.24 0.20 0.013 0.0014 0.018 0.0044 282.8
NGL Loading
Truck Loadout 2.67 - - 0.37 5.01
Fugitive Emissions
Component Leak Emissions - - 0.40 - - 0.038 18.05
Total Facility PTE = 96.59 111.42 36.61 4.88 7.17 10.47 183,353
Source
Uncontrolled Emissions Summary - Normal Operating Scenario
Controlled Emissions Summary - Normal Operating Scenario
Source
1. The normal operating scenario assumes the engines and processing will run continuously. In this scenario, the emergency generators will not operate as they are used to run the data centers
should the facility go down.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Formaldehyde Benzene Toluene Ethylbenzene Xylenes Methanol Acetaldehyde Acrolein
lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr
Engines
2 x Waukesha VGF H24SE 1.17E-01 1.62E-02 5.74E-03 2.55E-04 2.00E-03 3.15E-02 2.87E-02 2.70E-02
10 x Waukesha 9394GSI 2.76E+00 3.36E-01 1.19E-01 5.27E-03 4.15E-02 6.51E-01 5.93E-01 5.59E-01
Turbine
1 x Titan 130 9.45E-02 1.60E-03 1.73E-02 4.26E-03 8.52E-03 - 5.33E-03 8.52E-04
Dehydrators
TEG Dehydrator 1 - 4.18E-02 1.50E-03 4.11E-05 4.11E-05 - - -
TEG Dehydrator 2 - 4.18E-02 1.50E-03 4.11E-05 4.11E-05 - - -
Reboiler 1 4.04E-05 - - - - - - -
Reboiler 2 4.04E-05 - - - - - - -
NGL Loading
Truck Loadout - - - - - - - -
Fugitive Emissions
Component Leak Emissions - 2.79E-02 6.43E-03 2.00E-03 2.00E-03 - - -
Total Facility PTE = 2.97 0.47 0.15 0.012 0.054 0.68 0.63 0.59
Formaldehyde Benzene Toluene Ethylbenzene Xylenes Methanol Acetaldehyde Acrolein
lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr
Engines
2 x Waukesha VGF H24SE 2.34E-03 1.62E-02 5.74E-03 2.55E-04 2.00E-03 3.15E-02 2.87E-02 2.70E-02
10 x Waukesha 9394GSI 5.51E-02 2.55E-01 9.00E-02 4.00E-03 3.14E-02 4.93E-01 4.50E-01 4.24E-01
Turbine
1 x Titan 130 9.45E-02 1.60E-03 1.73E-02 4.26E-03 8.52E-03 - 5.33E-03 8.52E-04
Dehydrators
TEG Dehydrator 1 - 1.90E-02 9.00E-04 2.05E-05 2.05E-05 - - -
TEG Dehydrator 2 - 1.90E-02 9.00E-04 2.05E-05 2.05E-05 - - -
Reboiler 1 - - - - - - - -
Reboiler 2 - - - - - - - -
NGL Loading
Truck Loadout - - - - - - - -
Fugitive Emissions
Component Leak Emissions - 2.79E-02 6.43E-03 2.00E-03 2.00E-03 - - -
Total Facility PTE = 0.15 0.34 0.12 0.011 0.044 0.52 0.48 0.45
Uncontrolled Emissions Summary - Normal Operating Scenario
Source
Controlled Emissions Summary - Normal Operating Scenario
Source
1. The normal operating scenario assumes the engines and processing will run continuously. In this scenario, the emergency generators will not operate as they are used to run the data centers should the facility go
down.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
NOx CO VOC SO2 PM/PM10/PM2.5 HAPs CO2e
ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr
Engines
2 x Waukesha VGF H24SE 135.60 88.79 1.93 0.13 0.82 0.99 4,972
10 x Waukesha 9394GSI 2,827 1,336 28.23 2.75 2.28 21.85 102,880
Turbine
1 x Titan 130 55.04 33.50 19.19 1.72 3.63 0.56 64,404
Dehydrators
TEG Dehydrator 1 - - 7.83 - - 0.18 219.9
TEG Dehydrator 2 - - 7.83 - - 0.18 219.9
Reboiler 1 0.22 0.19 0.012 0.0013 0.017 0.0042 266.6
Reboiler 2 0.22 0.19 0.012 0.0013 0.017 0.0042 266.6
NGL Loading
Truck Loadout - - 2.52 - - 0.35 4.72
Fugitive Emissions
Component Leak Emissions - - 0.38 - - 0.036 17.02
Emergency Generator
2 x Caterpillar 3516 1.23 0.32 0.03 0.014 0.032 0.013 1,542.8
Total Facility PTE = 3,019 1,459 67.97 4.62 6.80 24.17 174,795
NOx CO VOC SO2 PM/PM10/PM2.5 HAPs CO2e
ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr
Engines
2 x Waukesha VGF H24SE 1.45 2.90 0.18 0.13 0.82 0.52 4,972
10 x Waukesha 9394GSI 34.14 68.29 6.83 2.75 2.28 8.24 102,880
Turbine
1 x Titan 130 55.04 33.50 19.19 1.72 3.63 0.56 64,404
Dehydrators
TEG Dehydrator 1 - - 2.69 - - 0.082 37.71
TEG Dehydrator 2 - - 2.69 - - 0.082 37.71
Reboiler 1 0.22 0.19 0.012 0.0013 0.017 0.0042 266.6
Reboiler 2 0.22 0.19 0.012 0.0013 0.017 0.0042 266.6
NGL Loading
Truck Loadout 2.52 - - 0.35 4.72
Fugitive Emissions
Component Leak Emissions - - 0.38 - - 0.036 17.02
Emergency Generator
2 x Caterpillar 3516 1.23 0.32 0.032 0.014 0.032 0.013 1,542.8
Total Facility PTE = 92.31 105.38 34.55 4.62 6.80 9.89 174,430
Uncontrolled Emissions Summary - Emergency Operating Scenario
Source
Controlled Emissions Summary - Emergency Operating Scenario
Source
1. The emergency operating scenario assumes the engines and processing will run for 8,260 hours per year with a maximum downtime of 500 hours per year. During this 500 hours, the diesel
emergency engines will operate. Both the facility and diesel engines will not operate at the same time.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Formaldehyde Benzene Toluene Ethylbenzene Xylenes Methanol Acetaldehyde Acrolein
lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr
Engines
2 x Waukesha VGF H24SE - - - - - - - -
10 x Waukesha 9394GSI - - - - - - - -
Turbine
1 x Titan 130 - - - - - - - -
Dehydrators
TEG Dehydrator 1 - - - - - - - -
TEG Dehydrator 2 - - - - - - - -
Reboiler 1 - - - - - - - -
Reboiler 2 - - - - - - - -
NGL Loading
Truck Loadout - - - - - - - -
Fugitive Emissions
Component Leak Emissions - - - - - - - -
Emergency Generator
EU04 - 2 x Caterpillar 3516 2.98E-03 2.93E-02 1.06E-02 - 7.28E-03 - 9.50E-04 2.97E-04
Total Facility PTE = 2.98E-03 2.93E-02 1.06E-02 0.00E+00 7.28E-03 0.00E+00 9.50E-04 2.97E-04
Formaldehyde Benzene Toluene Ethylbenzene Xylenes Methanol Acetaldehyde Acrolein
lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr
Engines
2 x Waukesha VGF H24SE - - - - - - -
10 x Waukesha 9394GSI - - - - - - -
Turbine
1 x Titan 130 - - - - - - -
Dehydrators
TEG Dehydrator 1 - - - - - - -
TEG Dehydrator 2 - - - - - - -
Reboiler 1 - - - - - - -
Reboiler 2 - - - - - - -
NGL Loading
Truck Loadout - - - - -
Fugitive Emissions
Component Leak Emissions - - - - - - -
Emergency Generator
EU04 - 2 x Caterpillar 3516 2.98E-03 2.93E-02 1.06E-02 - 7.28E-03 - 9.50E-04 0.0
Total Facility PTE = 2.98E-03 2.93E-02 1.06E-02 0.00E+00 7.28E-03 0.00E+00 9.50E-04 0
Uncontrolled Emissions Summary - Emergency Operating Scenario
Source
Controlled Emissions Summary - Emergency Operating Scenario
Source
1. During the emergency scenario, only diesel engines will operate in an hour.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Source Information
Emission Unit ID:
Engine Make/Model
Service
Controls - Y or N / Type Y NSRC/AFRC
Number of Operational Units 2 engine
Horsepower Rating1 1,060 horsepower
Fuel Consumption (BSFC)1 9,698 Btu/(hp-hr)
Heat Rating2 10.28 MMBtu/hr
Fuel Consumption2 67.03 MMscf/yr
Fuel Consumption2 7,652 scf/hr
Fuel Heating Value3 1,343 Btu/scf
Operating Hours 8,760 hrs/yr
lb/MMBtu g/hp-hr lb/hr ton/yr lb/MMBtu g/hp-hr lb/hr ton/yr
NOx - 14.05 32.83 143.8 - 0.15 0.35 1.54 Manufacturer Specifications
CO - 9.20 21.50 94.17 - 0.30 0.70 3.07 Manufacturer Specifications
VOC - 0.20 0.47 2.05 - 0.019 0.044 0.19 Manufacturer Specifications
SO2 3.13E-03 - 0.032 0.14 3.13E-03 - 0.032 0.14 Converted for a gas with maximum H2S of 25 ppmv
PM10 1.94E-02 - 0.20 0.87 1.94E-02 - 0.20 0.87 AP-42, Chapter 3.2, Table 3.2-3
PM2.5 1.94E-02 - 0.20 0.87 1.94E-02 - 0.20 0.87 AP-42, Chapter 3.2, Table 3.2-3
1,1,2,2-Tetrachloroethane 2.53E-05 - 2.60E-04 1.14E-03 2.29E-05 - 2.60E-04 1.14E-03 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
1,3-Butadiene 6.63E-04 - 6.82E-03 2.99E-02 6.00E-04 - 6.82E-03 2.99E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Acetaldehyde 2.79E-03 - 2.87E-02 1.26E-01 2.52E-03 - 2.87E-02 1.26E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Acrolein 2.63E-03 - 2.70E-02 1.18E-01 2.38E-03 - 2.70E-02 1.18E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Benzene 1.58E-03 - 1.62E-02 7.11E-02 1.43E-03 - 1.62E-02 7.11E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Ethylbenzene 2.48E-05 - 2.55E-04 1.12E-03 2.24E-05 - 2.55E-04 1.12E-03 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Formaldehyde - 0.050 1.17E-01 5.12E-01 - 0.001 2.34E-03 1.02E-02 Manufacturer Specifications
Methanol 3.06E-03 - 3.15E-02 1.38E-01 2.77E-03 - 3.15E-02 1.38E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Methylene Chloride 4.12E-05 - 4.24E-04 1.86E-03 3.73E-05 - 4.24E-04 1.86E-03 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
PAH 1.41E-04 - 1.45E-03 6.35E-03 1.41E-04 - 1.45E-03 6.35E-03 AP-42, Chapter 3.2, Table 3.2-3
Toluene 5.58E-04 - 5.74E-03 2.51E-02 5.05E-04 - 5.74E-03 2.51E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Xylenes 1.95E-04 - 2.00E-03 8.78E-03 1.76E-04 - 2.00E-03 8.78E-03 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Other HAPs4 2.10E-04 - 2.16E-03 9.45E-03 2.10E-04 - 2.16E-03 9.45E-03 AP-42, Chapter 3.2, Table 3.2-3
Total HAPs 1.19E-02 0.24 1.05 1.08E-02 0.12 0.55
kg/MMBtu g/hp-hr lb/hr ton/yr kg/MMBtu g/hp-hr lb/hr ton/yr
CO2 53.06 - 1,203 5,268 53.06 - 1,203 5,268 40 CFR Part 98 Subpart C Table C-1
CH4 0.001 - 0.023 0.099 0.001 - 0.023 0.099 40 CFR Part 98 Subpart C Table C-2
N2O 0.0001 - 0.0023 0.0099 0.0001 - 0.0023 0.0099 40 CFR Part 98 Subpart C Table C-2
CO2e - - 1,204 5,273 - - 1,204 5,273 Global warming potentials of 40 CFR Part 98 Table A-1
Notes:
1. Manufactuer specifications.
2. Calculated values.
3. Estimated heating value of the fuel gas.
4. Other HAPs include those HAPs listed in AP-42 below the detection thresholds.
Pollutant Emission Factor Controlled Emissions Source of Emissions Factors
Compressor Engine Emissions
BOOST1 & BOOST2
Waukesha VGF H24SE
Fuel Gas Booster Compression
Pollutant Emission Factor Controlled Emissions Source of Emissions FactorsUncontrolled Emissions Emission Factor
Emission FactorUncontrolled Emissions
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Source Information
Emission Unit ID:
Engine Make/Model
Service
Controls - Y or N / Type Y NSRC/AFRC
Number of Operational Units 10 engine
Horsepower Rating1 25,000 horsepower
Fuel Consumption (BSFC)1 8,508 Btu/(hp-hr)
Heat Rating2 212.70 MMBtu/hr
Fuel Consumption2 1,387.0 MMscf/yr
Fuel Consumption2 158,328 scf/hr
Fuel Heating Value3 1,343 Btu/scf
Operating Hours 8,760 hrs/yr
lb/MMBtu g/hp-hr lb/hr ton/yr lb/MMBtu g/hp-hr lb/hr ton/yr
NOx - 12.42 684.5 2,998 - 0.15 8.27 36.21 Manufacturer Specifications
CO - 5.87 323.5 1,417 - 0.30 16.53 72.42 Manufacturer Specifications
VOC - 0.12 6.83 29.93 - 0.03 1.65 7.24 Manufacturer Specifications
SO2 3.13E-03 - 0.66 2.91 3.13E-03 - 0.66 2.91 Converted for a gas with maximum H2S of 25 ppmv
PM10 - 0.01 0.55 2.41 - 0.01 0.55 2.41 Manufacturer Specifications
PM2.5 - 0.01 0.55 2.41 - 0.01 0.55 2.41 Manufacturer Specifications
1,1,2,2-Tetrachloroethane 2.53E-05 - 5.38E-03 2.36E-02 1.92E-05 - 4.08E-03 1.79E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
1,3-Butadiene 6.63E-04 - 1.41E-01 6.18E-01 5.03E-04 - 1.07E-01 4.68E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Acetaldehyde 2.79E-03 - 5.93E-01 2.60E+00 2.12E-03 - 4.50E-01 1.97E+00 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Acrolein 2.63E-03 - 5.59E-01 2.45E+00 1.99E-03 - 4.24E-01 1.86E+00 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Benzene 1.58E-03 - 3.36E-01 1.47E+00 1.20E-03 - 2.55E-01 1.12E+00 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Ethylbenzene 2.48E-05 - 5.27E-03 2.31E-02 1.88E-05 - 4.00E-03 1.75E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Formaldehyde - 0.050 2.76E+00 1.21E+01 - 0.001 5.51E-02 2.41E-01 Manufacturer Specifications
Methanol 3.06E-03 - 6.51E-01 2.85E+00 2.32E-03 - 4.93E-01 2.16E+00 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Methylene Chloride 4.12E-05 - 8.76E-03 3.84E-02 3.12E-05 - 6.64E-03 2.91E-02 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
PAH 1.41E-04 - 3.00E-02 1.31E-01 1.41E-04 - 3.00E-02 1.31E-01 AP-42, Chapter 3.2, Table 3.2-3
Toluene 5.58E-04 - 1.19E-01 5.20E-01 4.23E-04 - 9.00E-02 3.94E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Xylenes 1.95E-04 - 4.15E-02 1.82E-01 1.48E-04 - 3.14E-02 1.38E-01 AP-42, Chapter 3.2, Table 3.2-3; reduced by same percentage as VOC
Other HAPs4 2.10E-04 - 4.46E-02 1.95E-01 2.10E-04 - 4.46E-02 1.95E-01 AP-42, Chapter 3.2, Table 3.2-3
Total HAPs 1.19E-02 5.29 23.17 9.12E-03 1.99 8.74
kg/MMBtu g/hp-hr lb/hr ton/yr kg/MMBtu g/hp-hr lb/hr ton/yr
CO2 53.06 - 24,885 108,996 53.06 - 24,885 108,996 40 CFR Part 98 Subpart C Table C-1
CH4 0.001 - 0.47 2.05 0.001 - 0.47 2.05 40 CFR Part 98 Subpart C Table C-2
N2O 0.0001 - 0.047 0.21 0.0001 - 0.047 0.21 40 CFR Part 98 Subpart C Table C-2
CO2e - - 24,911 109,108 - - 24,911 109,108 Global warming potentials of 40 CFR Part 98 Table A-1
Notes:
1. Manufactuer specifications.
2. Calculated values.
3. Estimated heating value of the fuel gas.
4. Other HAPs include those HAPs listed in AP-42 below the detection thresholds.
Pollutant Emission Factor Controlled Emissions Source of Emissions Factors
Generator Engine Emissions
GEN1 through GEN10
Waukesha 9394 GSI
Power Generation
Pollutant Emission Factor Controlled Emissions Source of Emissions FactorsEmission Factor
Emission Factor
Uncontrolled Emissions
Uncontrolled Emissions
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Source Information
Emission Unit ID:
Engine Make/Model
Service
Controls - Y or N / Type Y SoLoNox
Number of Operational Units 1 turbine
Power Rating1 13,634 kW
Fuel Consumption (BSFC)1 9,766 Btu/(kW-hr)
Heat Rating2 133.1 MMBtu/hr
Fuel Consumption2 868.2 MMscf/yr
Fuel Consumption2 99,115 scf/hr
Fuel Heating Value3 1,343 Btu/scf
Operating Hours 8,760 hrs/yr
lb/MMBtu g/hp-hr lb/hr ton/yr
NOx - 0.33 13.33 58.37 Manufacturer Specifications
CO - 0.20 8.11 35.53 Manufacturer Specifications
VOC - 0.12 4.65 20.35 Manufacturer Specifications - VOC is conservatively assumed to be 100% of HC
SO2 3.13E-03 - 0.42 1.82 Converted for a gas with maximum H2S of 25 ppmv
PM10 6.60E-03 - 0.88 3.85 AP-42, Chapter 3.1, Table 3.1-2a
PM2.5 6.60E-03 - 0.88 3.85 AP-42, Chapter 3.1, Table 3.1-2a
1,3-Butadiene 4.30E-07 - 5.73E-05 2.51E-04 AP-42, Chapter 3.1, Table 3.1-3
Acetaldehyde 4.00E-05 - 5.33E-03 2.33E-02 AP-42, Chapter 3.1, Table 3.1-3
Acrolein 6.40E-06 - 8.52E-04 3.73E-03 AP-42, Chapter 3.1, Table 3.1-3
Benzene 1.20E-05 - 1.60E-03 7.00E-03 AP-42, Chapter 3.1, Table 3.1-3
Ethylbenzene 3.20E-05 - 4.26E-03 1.87E-02 AP-42, Chapter 3.1, Table 3.1-3
Formaldehyde 7.10E-04 - 9.45E-02 4.14E-01 AP-42, Chapter 3.1, Table 3.1-3
Naphthalene 1.30E-06 - 1.73E-04 7.58E-04 AP-42, Chapter 3.1, Table 3.1-3
PAH 2.20E-06 - 2.93E-04 1.28E-03 AP-42, Chapter 3.1, Table 3.1-3
Propylene Oxide 2.90E-05 - 3.86E-03 1.69E-02 AP-42, Chapter 3.1, Table 3.1-3
Toluene 1.30E-04 - 1.73E-02 7.58E-02 AP-42, Chapter 3.1, Table 3.1-3
Xylenes 6.40E-05 - 8.52E-03 3.73E-02 AP-42, Chapter 3.1, Table 3.1-3
Total HAPS 1.03E-03 0.14 0.60
kg/MMBtu g/hp-hr lb/hr ton/yr
CO2 53.06 - 15,578 68,232 40 CFR Part 98 Subpart C Table C-1
CH4 0.001 - 0.29 1.29 40 CFR Part 98 Subpart C Table C-2
N2O 0.0001 - 0.029 0.13 40 CFR Part 98 Subpart C Table C-2
CO2e - - 15,594 68,303 Global warming potentials of 40 CFR Part 98 Table A-1
Notes:
1. Manufactuer specifications,
2. Calculated values.
3. Estimated heating value of the fuel gas.
Pollutant Emission Factor Annual Emissions Source of Emissions Factors
Turbine Emissions
TURBINE
Titan 130 Turbine
Power Generation
Pollutant Emission Factor Annual Emissions Source of Emissions Factors
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Source Information
Emission Unit ID:
Engine Make/Model
Service
Controls - Y or N / Type Y EPA-Certified
Number of Operational Units 2 engines
Total Horsepower Rating1 5,882 horsepower
Fuel Consumption (BSFC)1 275.2 gal/hr
Heat Rating2 37.71 MMBtu/hr
Fuel Consumption2 137,600 gal/yr
Fuel Density3 7.1 lb/gal
Fuel Heating Value3 19,300 Btu/lb
Operating Hours4 500 hrs/yr
lb/MMBtu g/hp-hr lb/hr ton/yr
NOx - 0.38 4.93 1.23 Manufacturer Specifications
CO - 0.10 1.30 0.32 Manufacturer Specifications
VOC - 0.01 0.13 0.03 Manufacturer Specifications
SO2 1.52E-03 - 0.057 0.014 AP-42, Chapter 3.4; maximum 15 ppm H2S
PM10 - 0.010 0.13 0.032 Manufacturer Specifications
PM2.5 - 0.010 0.13 0.032 Manufacturer Specifications
Acetaldehyde 2.52E-05 - 9.50E-04 2.38E-04 AP-42, Chapter 3.4, Table 3.4-3
Acrolein 7.88E-06 - 2.97E-04 7.43E-05 AP-42, Chapter 3.4, Table 3.4-3
Benzene 7.76E-04 - 2.93E-02 7.32E-03 AP-42, Chapter 3.4, Table 3.4-3
Formaldehyde 7.89E-05 - 2.98E-03 7.44E-04 AP-42, Chapter 3.4, Table 3.4-3
Toluene 2.81E-04 - 1.06E-02 2.65E-03 AP-42, Chapter 3.4, Table 3.4-3
Xylenes 1.93E-04 - 7.28E-03 1.82E-03 AP-42, Chapter 3.4, Table 3.4-3
Total HAPS 1.36E-03 0.051 0.013
kg/MMBtu g/hp-hr lb/hr ton/yr
CO2 73.96 - 6,150 1,537.5 40 CFR Part 98 Subpart C Table C-1
CH4 0.003 - 0.25 0.062 40 CFR Part 98 Subpart C Table C-2
N2O 0.0006 - 0.050 0.0125 40 CFR Part 98 Subpart C Table C-2
CO2e - - 6,171 1,542.8 Global warming potentials of 40 CFR Part 98 Table A-1
Notes:
1. Manufactuer specifications,
2. Calculated values.
3. AP-42 Section 3.4 Table 3.4-1 footnote a.
4. Manufacturer data shows compliace with EPA certification for emergency use.
Emergency Generator Emissions
EGEN1 & EGEN2
Caterpillar 3516
Emergency Power Generator
Pollutant Emission Factor Annual Emissions
Pollutant Emission Factor Annual Emissions
Source of Emissions Factors
Source of Emissions Factors
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Throughput: 4.00 MMscf/day
Number of EG Dehydrators 2 dehydrators
Potential Emissions per EG1 & EG2
lb/hr ton/yr lb/hr ton/yr
Uncontrolled Emissions 1
VOC 0.65 2.86 1.24 5.45
Total HAPs 0.020 0.087 0.023 0.10
Benzene 0.019 0.083 0.023 0.10
Toluene 0.00090 0.0040 0.00 0.00
Ethylbenzene 0.000021 0.000090 0.000021 0.000090
Xylenes 0.000021 0.000090 0.000021 0.000090
Methane 0.26 1.14 1.71 7.48
Carbon Dioxide 2.61 11.43 1.45 6.35
CO2e 9.13 39.99 44.12 193.2
Controlled Emissions 1,2
VOC 0.65 2.86 0.00 0.00
Total HAPs 0.020 0.087 0.00 0.00
Benzene 0.019 0.083 0.00 0.00
Toluene 0.00090 0.0040 0.00 0.00
Ethylbenzene 0.000021 0.000090 0.00 0.00
Xylenes 0.000021 0.000090 0.00 0.00
Methane 0.26 1.14 0.00 0.00
Carbon Dioxide 2.61 11.43 0.00 0.00
CO2e 9.13 39.99 0.00 0.00
lb/hr ton/yr
Uncontrolled Emissions 1
VOC 1.90 8.31
Total HAPs 0.043 0.19
Benzene 0.042 0.18
Toluene 0.0015 0.0068
Ethylbenzene 0.000041 0.00018
Xylenes 0.000041 0.00018
Methane 1.97 8.62
Carbon Dioxide 4.06 17.78
CO2e 53.25 233.2
Controlled Emissions 1,2
VOC 0.65 2.86
Total HAPs 0.020 0.087
Benzene 0.019 0.083
Toluene 0.00090 0.0040
Ethylbenzene 0.000021 0.000090
Xylenes 0.000021 0.000090
Methane 0.26 1.14
Carbon Dioxide 2.61 11.43
CO2e 9.13 39.99
Notes
EG Dehydrator Emissions
1. Output from GRI-GLYCalc 4.0. There are no detectable HAPs in the inlet gas so "Other Hexanes" are assumed to be all benzene,
Heptanes are assumed to be all toluene, and C*+ Heavies are assumed to be all ethylbenzene and xylenes.
2. Controlled emissions account for the flash tank gas being recycled. There are no controls on the still vent.
Pollutant Dehydrator Still Vent Flash Tank Gas
Emission Totals
Pollutant
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Number of Heaters: 1 heaters
Design Heat Rate: 0.55 MMBtu/hr
Hours of Operation: 8,760 hr/yr
Fuel Heat Value1: 1,343 Btu/scf
Fuel Use: 3.59 MMscf/yr
Emission Calculations per REB1 & REB2
Emission Factor Emissions Emissions Emission Factor
(lb/MMscf) lb/hr ton/yr Source
NOX 100.0 0.054 0.24 AP-42 Ch. 1.4 Table 1.4-1
CO 84.00 0.045 0.20 AP-42 Ch. 1.4 Table 1.4-1
VOC 5.50 0.0030 0.013 AP-42 Ch. 1.4 Table 1.4-2
TOC 11.00 0.0059 0.026 AP-42 Ch. 1.4 Table 1.4-2
PM/PM10/PM2.5 7.60 0.0041 0.018 AP-42 Ch. 1.4 Table 1.4-2
PM2.5 7.60 0.0041 0.018 AP-42 Ch. 1.4 Table 1.4-2
SO2 0.60 0.00032 0.0014 AP-42 Ch. 1.4 Table 1.4-2
Formaldehyde 0.075 0.000040 0.00018 AP-42 Ch. 1.4 Table 1.4-3
Total HAPs 1.88 0.0010 0.0044 AP-42 Ch. 1.4 Table 1.4-3
Emission Factor Emissions Emissions Emission Factor
(kg/MMBtu) lb/hr ton/yr Source
Carbon Dioxide 53.06 64.49 282.5 40 CFR Part 98, Subpart C, Table C-1
Methane 0.0010 0.0012 0.0053 40 CFR Part 98, Subpart C, Table C-2
Nitrous Oxide 0.00010 0.00012 0.00053 40 CFR Part 98, Subpart C, Table C-2
CO2e --- 64.56 282.8 40 CFR Part 98, Subpart A, Table A-1
Notes
1. Heating value of the fuel gas based on expected wet gas analysis.
Natural Gas Fueled Dehydrator Reboiler Emissions
Pollutant
Pollutant
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
793
Connection diameter:0.25 ft
Length between valves:5.00 ft
Connection volume:0.25 ft3
Annual connection volume vented: 194.6 ft3
NGL density: 31.21 lb/ft3
Annual NGL vented: 6,075 lb/year
NGL VOC content: 88.05 by weight1
NGL CH4 content: 6.57 by weight1
NGL CO2 content: 0.54 by weight1
NGL Benzene content: 8.95 by weight1
NGL Toluene content: 2.12 by weight1
NGL Ethylbenzene content: 0.53 by weight1
NGL Xylene content: 0.53 by weight1
Pollutant ton/yr
Uncontrolled Emissions
VOC 2.67
CH4 0.20
CO2 0.016
CO2e 5.01
Benzene 0.27
Toluene 0.064
Ethylbenzene 0.016
Xylenes 0.016
Notes
NGL Truck Loading Emissions
2. NGLs will be stored under pressure until loadout. Therefore NGL storage will not result
in emissions to atmosphere.
1. Liquid weight composition from GLYCalc Cold Separator Oil Stream.
Load Line
Estimated maximum number of truck loads per year:
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Number THC Emission VOC VOC
Unit Type Service of Factor2 Emissions3 Emissions3
Units 1 kg/hr-unit lb/hr tons/yr
Valves Gas 530 2.50E-05 0.029 0.13
Pump Seals Gas 10 3.50E-04 0.0076 0.03
Others Gas 4 1.20E-04 0.0010 0.0045
Connectors Gas 1,940 1.00E-05 0.042 0.18
Flanges Gas 402 5.70E-06 0.0050 0.022
Open Ended Lines Gas 100 1.50E-05 0.0032 0.014
Total Gas 0.087 0.38
Valves Water/Ethylene Glycol 18 9.70E-06 0.00038 0.0017
Pump Seals Water/Ethylene Glycol 2 2.40E-05 0.00011 0.00046
Others Water/Ethylene Glycol 2 5.90E-05 0.00026 0.0011
Connectors Water/Ethylene Glycol 184 1.00E-05 0.0041 0.018
Flanges Water/Ethylene Glycol 10 2.90E-06 0.000064 0.00028
Open Ended Lines Water/Ethylene Glycol 8 3.50E-06 0.000062 0.00027
Total EG 0.0049 0.022
Fugitive Emissions3
Component lb/hr ton/yr
VOC 0.092 0.40
CO2 0.0052 0.023
CH4 0.165 0.72
CO2e 4.12 18.05
Benzene 0.0064 0.028
Toluene 0.0015 0.0064
Ethylbenzene 0.00046 0.0020
Xylenes 0.00046 0.0020
Notes
1. Component counts estimated based on similar facility layouts.
2. Emission factors from EPA-453/R-95-017, Table 2-8 less than 10,000 ppmv.
3. VOC weight percentages are based on gas analysis for gas components and assumed to be 100% for water/ethylene glycol components.
Component Fugitive Emissions
4. Speciated compound emissions are based on weight fractions between VOC and compound.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
MOL %MW
Component
Weight
lb/lb-mol
Methane 74.76 16.04 11.99 0.53
Ethane 12.48 30.07 3.75 0.17
Propane 6.33 44.10 2.79 0.12
i-Butane 0.92 58.12 0.53 0.024
n-Butane 2.33 58.12 1.35 0.060
i-Pentane 0.59 72.15 0.43 0.019
n-Pentane 0.93 72.15 0.67 0.030
Hexanes 0.53 86.18 0.46 0.020
Heptanes 0.11 100.2 0.11 0.0047
Octanes 0.029 114.2 0.033 0.0015
Nonanes 0.0017 128.3 0.0022 0.000097
Decanes 0.00 142.3 0.00 0.00
n-Hexane 0.00 86.18 0.00 0.00
Benzene 0.00 78.11 0.00 0.00
Toluene 0.00 92.14 0.00 0.00
Ethylbenzene 0.00 106.2 0.00 0.00
Xylenes 0.00 106.2 0.00 0.00
Nitrogen 0.15 28.01 0.042 0.0018
Carbon Dioxide 0.86 44.01 0.38 0.017
Oxygen 0.00 32.01 0.00 0.00
Hydrogen Sulfide 0.00 34.08 0.00 0.00
Totals 100.0 22.53 1.00
Heating Value (Btu/scf) 1,343
Molecular weight 22.53
VOC weight fraction 0.28
CH4 weight fraction 0.53
HAP weight fraction 0.00
THC weight fraction 0.98
VOC of THC wt fraction 0.29
HAP of THC wt fraction 0.00
CH4 of THC wt fraction 0.54
Notes:
Facility Wet Gas Analysis
Component Wt. Fraction
1. Wet gas analysis is representative.
Snapper Facility Initial Title V Operating Application
Crusoe Energy Systems, Inc.
Duchesne County, Utah
Appendix E – Insignificant Emission Units
The following list includes activities and/or emissions units that may be present or operational at the Facility.
Air conditioning or ventilating equipment not designed to remove air contaminants generated by or
released from associated equipment.
Equipment using water, water and soap or detergent, or a suspension of abrasives in water for purposes
of cleaning or finishing provided no organic solvent has been added to the water, the boiling point of the
additive is not less than 100 degrees Celsius (212 degrees Fahrenheit), and the water is not heated above
65.5 degrees Celsius (150 degrees Fahrenheit).
Administrative activities including, but not limited to, paper shredding, copying, photographic activities, and
blueprinting machines.
Housekeeping activities for cleaning purposes, including collecting spilled and accumulated materials at the
source, but not including use of cleaning materials that contain organic solvent.
Activities associated with the construction, on-site repair, maintenance or dismantlement of buildings,
utility lines, pipelines, wells, excavations, earthworks, and other structures that do not constitute emission
units.
Piping and storage systems for natural gas, propane, and liquified petroleum gas, excluding pipeline
compressor stations and associated storage facilities.
Lawn care, landscape maintenance, and groundskeeping activities.
Manually operated equipment used for buffing, polishing, carving, cutting, drilling, machining, routing,
sanding, sawing, scarfing, surface grinding or turning.
Firefighting activities and training in preparation for fighting fires conducted at the source.
Activities associated with the construction, repair, or maintenance of roads or other paved or open areas,
including operation of street sweepers, vacuum trucks, spray trucks and other vehicles related to the
control of fugitive emissions of such roads or other areas.
Activities at a source associated with the maintenance, repair, or dismantlement of an emission unit or
other equipment installed at the source, including preparation for maintenance, repair or dismantlement,
and preparation for subsequent startup, including preparation of a shutdown vessel for entry, replacement
of insulation, welding and cutting, and steam purging of a vessel prior to startup.
Gasoline, diesel fuel, or oil storage tanks with a capacity of 1,000 gallons or less and an annual throughput
of less than 40,000 gallons.
Air compressors and pneumatically operated equipment, including hand tools.
Air contaminant detectors or recorders, combustion controllers or shutoffs.
Combustion emissions from population of mobile sources.
Equipment used for quality control/assurance or inspection purposes, including sampling equipment used
to withdraw materials for analysis.
Equipment used for surface coating, painting, dipping or spray operations.
Portable electrical generators that can be moved by hand from one location to another.
Appendix F – Air Pollution Control Equipment
The following air pollution control equipment is installed and operational at the Facility.
A non-selective catalytic reduction (NSCR) device and an air-fuel ratio controller (AFRC) are installed on
each compressor engine (BOOST1 & BOOST2) to reduce NOx, CO, VOC, and HAP emissions.
o Inlet and outlet catalyst temperature monitoring is operational on each compressor engine.
o Inlet and outlet catalyst pressure monitoring is operational on each compressor engine.
A non-selective catalytic reduction (NSCR) device and an air-fuel ratio controller (AFRC) are installed on
each generator engine (GEN1 through GEN10) to reduce NOx, CO, VOC, and HAP emissions.
o Inlet and outlet catalyst temperature monitoring is operational on each generator engine.
o Inlet and outlet catalyst pressure monitoring is operational on each generator engine.
SoLoNOx controlled is built with the turbine (TURBINE) to reduce NOx emissions.
No forms are available for NSCR devices or low NOx control technology for engines or turbines, respectively.
Please refer to the details provided in Appendix D on the output emissions rates for the control equipment
listed above.
Appendix G – Compliance Monitoring Devices & Test Methods
Compliance Monitoring Devices & Activities
Custody meter – a custody meter onsite is used to direct only field gas fuel to the compressor engines
and then onto the turbine as well as the generator engines. Only field gas is used to power this onsite
combustion equipment.
Fuel specification – for the unpredictable emergency operation of the emergency diesel generator engines,
purchased diesel fuel will be specified to be ultra-low sulfur diesel (ULSD).
Run Time – in the unpredictable and emergency event of the operation of the emergency diesel generator
engines, hours of operation will be recorded using a non-resettable hour meter for each emergency diesel
generator engine.
Regular maintenance – regular maintenance as prescribed by manufacturer specifications is conducted on
the compressor engines, turbine, generator engines along with their associated control equipment namely
the NSCR, AFRC, and SoLoNOx. Similarly, the diesel generator engines follow manufacturer and EPA-
certification maintenance procedures and schedules to maintain the Tier 4 certification.
Regular inspections – Onsite facility inspections take place regularly to monitor the combustion equipment
including the unlikely presence of smoke. Remotely, data on load and power outputs are reviewed for any
automatic shutdown of equipment that may require needs for repair or maintenance.
Catalyst temperature monitoring – inlet and outlet catalyst temperature monitoring is operational on the
compressor engines and generator engines to detect temperature anomalies that may indicate the need
for maintenance or improper operation of the emission units or their control equipment.
Catalyst pressure monitoring – inlet and outlet catalyst pressure monitoring is operational on the
compressor engines and generator engines to detect pressure and/or differential pressure anomalies that
may indicate the need for maintenance or improper operation of the emission units or their control
equipment.
Test Methods
40 CFR Part 60 Appendix A Methods 7, 7E or other EPA-approved testing methods are used to
demonstrate compliance with applicable NOx emissions limits on the compressor engines (BOOST1 &
BOOST2), turbine (TURBINE), generator engines (GEN1 through GEN10).
40 CFR Part 60 Appendix A Method 10 or other EPA-approved testing methods are used to demonstrate
compliance with applicable CO emissions limits on the compressor engines (BOOST1 & BOOST2), turbine
(TURBINE), generator engines (GEN1 through GEN10).
40 CFR Part 60 Appendix A Methods 18, 25, 25A, 40 CFR Part 63 Appendix A Method 320, or other EPA-
approved testing methods are used to demonstrate compliance with applicable VOC emissions limits on
the compressor engines (BOOST1 & BOOST2), turbine (TURBINE), generator engines (GEN1 through
GEN10).
No other equipment or activities, permitted or otherwise, is operational at the Facility. Therefore, no other
monitoring or test methods are required.
Appendix H – Regulatory Discussion
Utah State Regulations – State Implementation Plan
Utah Administrative Code: R307 - Air Quality
I. UAC R307-107 – General Requirements: Breakdowns
If the Facility experiences a breakdown, the Facility will report the incident via telephone, electronic
mail, or fax within 24 hours of the incident. The Facility will also report the breakdown to UDAQ in
writing within fourteen days of the initial breakdown, including a corrective program directed at
preventing future incidents. The written report will include the cause and nature of the event,
estimated quantity of pollutants emitted, time of emissions, and steps to control the emissions and
prevent recurrence.
In the event the Facility suffers an unavoidable breakdown, the Facility will ensure that emission
limitations and visible emission limitations are exceeded for only as short a period of time as reasonable.
The owner or operator shall take all reasonable measures to limit the total emissions from the source.
This rule is applicable.
II. UAC R307-150 – Emissions Inventories
The Facility will submit an emissions inventory report on or before April 15 of each year following the
calendar year for which an inventory is required. The Facility will submit the emissions inventory report
every third year for all emission units, including fugitive emissions. The Facility will submit an inventory
for each year in which the individual amount of PM10, SO2, NOx, CO, or VOCs increases or decreases
by 40 tons or more per year from the most recently submitted inventory. The emission inventory will
include individual pollutant totals of all chargeable pollutants not exempted in R307-150-8.
The Facility will maintain a copy of the emission inventory submitted to the UDAQ and records
indicating how the submitted information was determined, including any calculations, data,
measurements, and estimates used. This rule is applicable.
III. UAC R307-201 – Emissions Standards: General Emission Standards
R307-201 establishes emission standards for all areas of the state except for sources listed in section
IX, Part H of the SIP or located in a PM10 nonattainment or maintenance area.
Visible emissions from all emission points at the Facility shall be of a shade or density no darker than
20 percent opacity. This rule is applicable.
IV. UAC R307-325 – Ozone Nonattainment and Maintenance Areas: General Requirements
The rule establishes general requirements for control of VOCs in any ozone nonattainment or
maintenance area. The Facility is located in an ozone attainment area; therefore, this rule is applicable.
V. UAC R307-401 – Permit: New and Modified Sources (exemptions)
Establishes the application and permitting requirements for new installations and modifications to
existing installations throughout the State of Utah. This rule is applicable.
VI. UAC R307-401-5 – Notice of Intent
Any person subject to R307-401 shall submit a NOI to the executive secretary and receive an AO
prior to initiation of construction, modification, or relocation. This rule is applicable.
VII. UAC R307-403 – Permits: New and Modified Sources in Nonattainment Areas and Maintenance Areas
Specific permit requirements for new and modified sources in nonattainment and maintenance areas.
The Facility is located in an ozone nonattainment area; therefore, this rule is applicable.
VIII. UAC R307-406 – Visibility
The facility is a major source of emissions for CO. This rule is applicable.
IX. UAC R307-410 – Permits: Emissions Impact Analysis
The Facility has estimated potential emissions over 40 ton/yr of nitrogen oxides (NOx), over 100
ton/yr CO, and below other criteria pollutant modeling thresholds. This rule is applicable.
X. UAC R307-415 – Permits: Operating Permit Requirements
The facility is a major source of emissions for CO. This rule is applicable.
Code of Federal Regulations (CFR)
40 CFR Part 60 – Standards of Performance for New Stationary Sources
I. Subpart A – General Provision
Applicability: Subpart A applies to all equipment or facilities subject to an NSPS Subpart. Thus, the
Facility is applicable to Subpart A as the facility is considered an “affected facility” subject to the
general provisions of NSPS.
II. Subpart IIII – Standards of Performance for Stationary Compression Ignition Internal Combustion Engines
Applicability: Subpart IIII applies to stationary compression ignition internal combustion engines (CI
ICE) that were ordered after July 11, 2005, and manufactured after July 1, 2006. Therefore, the Facility
is applicable to Subpart IIII as the emergency diesel generators were ordered after July 11, 2005, and
manufactured after July 1, 2006. They are certified to EPA standards and will operate as emergency
units.
III. Subpart JJJJ – Standards of Performance for Stationary Spark Ignition Internal Combustion Engines
Applicability: Subpart JJJJ 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, the Facility is applicable to Subpart JJJJ as the compressor engines and
generator engines were ordered after June 12, 2006, and manufactured after July 1, 2007.
IV. Subpart KKKK - Standards of Performance for Stationary Combustion Turbines
Applicability: Subpart KKKK applies to 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
(§60.4305(a)). Thus, the Facility is applicable to Subpart KKKK 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.
Based on the installed and operational equipment at the Facility, neither 40 CFR Part 60 Subpart OOOOa nor
OOOOb currently apply to the Facility. The subject equipment would be the permitted EG dehydrators,
reboilers, bullet tanks, loadout points and other components that meet the definition of a “natural gas
processing plant” under the regulations. Since this equipment and associated processes are not current
emission units at the Facility, neither Subpart OOOOa nor OOOOb are applicable.
40 CFR Part 63 – National Emission Standards for Hazardous Air Pollutants for Source Categories
I. Subpart ZZZZ – National Emissions Standards for HAPs for Stationary Reciprocating Internal Combustion
Engines (RICE)
Applicability: Subpart ZZZZ applies to stationary RICE at a major or area source of HAP emissions
(§63.6585). A major source determination under Subpart ZZZZ for production field facilities (namely
those before a gas processing plant) aggregate HAP emissions from dehydration units, storage vessels,
combustion turbines, and reciprocating internal combustion engines. Since the Facility is a production
field facility under Subpart ZZZZ only the HAP emissions from the engines and turbine are aggregated
resulting in total HAP emissions less than 25 tons per year. The Facility is applicable to Subpart ZZZZ
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 since the Facility is an area
source of HAP emissions (§63.6590(c)(1)). Additionally, the emergency diesel generator engines are
new CI ICE and will meet Subpart ZZZZ by meeting 40 CFR Part 60, Subpart IIII since the Facility is
an area source of HAP emissions (§63.6590(c)(1)).
Based on the installed and operational equipment at the Facility, 40 CFR Part 63 Subpart HH currently does
not apply to the Facility. The subject equipment would be the permitted EG dehydrators. Since this equipment
and associated processes are not current emission units at the Facility, Subpart HH is not applicable.
Approval Order
Section 1: General Provisions
Each of the general provisions apply to the Facility. They are summarized below for completeness.
1.1 Definition, terms, abbreviations, and references
1.2 Limit exceedance disallowed without prior approval
1.3 Modification review and approval
1.4 Records retention and review by Utah Division of Air Quality (UDAQ)
1.5 Good air pollution control practices for minimizing emissions
1.6 Breakdown requirements
1.7 Emission inventory requirements
1.8 Construction timeline and notification requirements
Section I1: Permitted Equipment
II.A lists all equipment permitted to be installed and operated at the Facility. The Facility did not install the
two (2) EG dehydrators, two (2) boilers, or three (3) pressurized storage tanks.
II.B.1 identifies the compressor engine, turbine, and generator engine requirements that are fueled by
natural gas.
II.B.2 identifies the applicable NOx, CO, and VOC emissions limits for the compressor engines, turbine,
and generator engines along with the appropriate testing, notification, and reporting requirements.
II.B.3 identifies the limitations on the emergency diesel generator engines including opacity, run-time in
non-emergency situations, fuel standards, and EPA certification.
II.B.4 is not applicable as the subject equipment to the leak detection and repair requirements is not
installed or operational.
Appendix K – Compliance Plan and Schedule
Utah Administrative Code: R307 - Air Quality
I. UAC R307-107 – General Requirements: Breakdowns
o The Facility is in compliance at the time of this application submittal. No breakdowns occurred during
the first year of operation. Should an unavoidable breakdown occur in the future, the Facility will
continue to comply with the breakdown requirements where emission limitations and visible emission
limitations are exceeded for only as short a period of time as reasonable. Crusoe shall take all
reasonable measures to limit the total emissions from the source.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring, including duration of breakdown, any visible emissions, and measures to minimize
emissions, will be conducted. Records of each breakdown will be kept and reported to UDAQ, as
required.
II. UAC R307-150 – Emissions Inventories
o The Facility is in compliance at the time of this application submittal. The 2023 emissions inventory
was submitted to UDAQ prior to the April 15, 2024, deadline. The Facility will continue to comply
with the emissions inventory requirements for future calendar years.
o The requirement was effective starting January 1, 2024. The Facility will continue to maintain
compliance and keep records of the submitted emissions inventory and back-up calculations, data,
measurements, and estimates used.
o Emissions calculation records will be kept for each emissions inventory submittal. Data monitored
during the calendar year including fuel consumed, fuel gas specification such as H 2S concentrations and
heat value, and stack test results will be recorded, as needed, but at least annually to conduct the
emissions inventory. Reports will be submitted by April 15th of each year.
III. UAC R307-201 – Emissions Standards: General Emission Standards
o The Facility is in compliance at the time of this application submittal. Regular visible emissions checks
are conducted to ensure there are no visible emissions. The Facility will continue to comply with the
general emissions standards.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring of visible emissions checks will be done regularly using either Method 9 to measure opacity
or Method 22 to determine if visible emissions occur. Records of visible emissions checks will continue
to be kept for the combustion equipment. Any corrective actions following visible emissions checks
will be kept and reports will be submitted, if required.
IV. UAC R307-325 – Ozone Nonattainment and Maintenance Areas: General Requirements
o The Facility is in compliance at the time of this application submittal. No VOCs were spilled,
discarded, stored in open containers, or handled in a manner that would have resulted in greater
evaporation of VOCs than would have been if reasonably available control technology had been
applied. The Facility will continue to comply with the general emissions standards.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Crusoe will monitor and record any instances of evaporation of VOCs. As the Facility is comprised of
combustion equipment, there is no likely instance for VOC evaporation.
V. UAC R307-401 – Permit: New and Modified Sources (exemptions)
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. Should a
modification or new emissions unit be proposed for the Facility, Crusoe will submit the application
and meet the minimum requirements of a complete application for UDAQ review.
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Should any modifications be made to the Facility,
a NOI modification application will be submitted to UDAQ prior to commencement of the change.
VI. UAC R307-401-5 – Notice of Intent
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. Should a
modification or new emissions unit be proposed for the Facility, Crusoe will submit the application
and meet the minimum requirements of a complete application for UDAQ review.
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. The NOI submittal in September of 2022 fulfilled
the requirement of R307-401-5. Should any modifications be made to the facility, a NOI modification
application will be submitted to UDAQ prior to commencement of the change.
VII. UAC R307-403 – Permits: New and Modified Sources in Nonattainment Areas and Maintenance Areas
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. Should a
modification or new emissions unit be proposed for the Facility, Crusoe will submit the application
and meet the minimum requirements of a complete application for UDAQ review including best
available control technology (BACT).
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Crusoe demonstrated the equipment at the
Facility will operate through BACT. The Facility was constructed and operates as indicated in the
application submitted to UDAQ in September of 2022. Should any modifications be made to the facility,
a NOI modification application will be submitted to UDAQ prior to commencement of the change.
VIII. UAC R307-406 – Visibility
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. As the
Facility is major for CO in an area that is in attainment for CO, permit conditions were added for
which Crusoe conducts regular visible emissions to ensure no visible emissions.
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o Monitoring of visible emissions checks will be done regularly using either Method 9 to measure opacity
or Method 22 to determine if visible emissions occur. Records of visible emissions checks will continue
to be kept for the combustion equipment. Any corrective actions following visible emissions checks
will be kept and reports will be submitted, if required.
IX. UAC R307-410 – Permits: Emissions Impact Analysis
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. A dispersion
modeling emissions impact analysis was submitted as part of that application An emissions impact
analysis for NOx and CO was included and approved as part of the NOI/AO approval process. The
Facility was built in accordance with the equipment locations, stack parameters, and building
dimensions submitted with the emissions impact analysis.
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Crusoe demonstrated the equipment at the
Facility will maintain compliance with the NAAQS based on the permitted emissions rates, stack
parameters, and locations. The Facility was constructed and operates as indicated in the application
submitted to UDAQ in September of 2022. Should any modifications be made to the facility that
requires a revised emissions impact analysis, a revised NAAQS demonstration will be submitted to
UDAQ for review and approval.
X. UAC R307-415 – Permits: Operating Permit Requirements
o The Facility is in compliance at the time of this application submittal. This application is being
submitted within 12 months of the startup of the Facility which took place June 9, 2023 and meets the
requirements of the Initial Title V Operating Permit Application.
o The requirement was effective no later than 12 months from the startup of the Facility. The Facility
will continue to maintain compliance.
o Crusoe will maintain records of the submittals and permit documents related to the Operating Permit.
No monitoring, reporting, or test methods are required for this regulation.
o The Facility will continue to maintain compliance with future compliance reports effective during the
term including semiannual (every 6-months) compliance reports, annual compliance reports, and a
Title V Renewal Application. Crusoe proposes to submit semiannual compliance reports no later than
August 15th for the semiannual period of January through June and February 15th for the semiannual
period of July through December. Crusoe proposes to submit annual compliance reports no later than
February 15th for the annual period of January through December. Lastly, Crusoe will submit a Title V
Renewal Application no earlier than eighteen months before and no later than 6 months before the
expiration of the Title V permit which will be determined by the effective date of the Title V permit
plus 5 years.
Code of Federal Regulations (CFR)
40 CFR Part 60 – Standards of Performance for New Stationary Sources
I. Subpart A – General Provision
o The Facility is in compliance at the time of this application submittal. The general provisions are being
met by following the appropriate notification and reporting requirements as incorporated by reference
from 40 CFR Part 60 Subpart IIII and JJJJ. As previously mentioned, with the installed equipment at the
location, the Facility is not subject to 40 CFR Part 60 Subpart OOOOa nor Subpart OOOOb.
o The requirement was effective upon construction of the Facility. The Facility will continue to maintain
compliance.
o Crusoe submitted the startup notifications for the compressor engines, turbine, and generator engines
within 15 days of startup of each unit as required by 40 CFR Part 60.7. At this time, the emergency
diesel generator engines have not yet operated at the Facility.
o The Facility will continue to maintain compliance with the general provisions. Test methods referenced
by 40 CFR Part 60 Subpart JJJJ in the general provisions will be utilized for stack testing compliance
demonstrations. Notifications and reports will be submitted as required for startup of permitted
equipment subject to a 40 CFR Part 60 regulation or should a like-kind replacement occur. Records
of notifications will also be kept on file for a minimum of 5 years.
II. Subpart IIII – Standards of Performance for Stationary Compression Ignition Internal Combustion Engines
o The Facility is in compliance at the time of this application submittal. The emergency diesel generator
engines have not yet operated at the Facility. The emergency diesel generator engines are certified by
the manufacturer to meet Tier 4 emissions standards that are at or below 40 CFR Part 60 Subpart IIII
emissions standards. In order to maintain the certification, Crusoe will maintain and operate the
emergency diesel generators per manufacturer and certification procedures. By following the
manufacturer and certification procedures, only recordkeeping requirements will need to be followed
and no additional testing is required.
o These requirements will be effective upon installation and operation of the emergency diesel generator
engines. At this time, the emergency diesel generator engines have not yet operated at the Facility.
The Facility will continue to maintain compliance.
o Monitoring requirements, including fuel specifications, will continue to be followed. Records of
maintenance and adherence to the certification-related procedures will be kept for a minimum of 5
years. Lastly, as the emergency diesel generator engines will be used for emergency purposes only,
run-time will be monitored and recorded using a non-resettable hour meter and circumstances for
their operation will be recorded.
III. Subpart JJJJ – Standards of Performance for Stationary Spark Ignition Internal Combustion Engines
o The Facility is in compliance at the time of this application submittal. The compressor engines and
generator engines meet the emissions standards of 40 CFR Part 60 Subpart JJJJ by conducting
performance tests following the appropriate methods of the rule. The generator engines were tested
in October and November of 2023 within 180 days of startup of each unit at the Facility. The
compressor engines were tested in December of 2023 within 180 days of startup of each unit at the
Facility. The protocol and notification of each test date were submitted at least 30 days prior to the
test and the test reports were submitted within 60 days of the test dates. At this time, there has been
no propane used in the compressor engines and generators nor is the expectation that propane will
be used.
o These requirements were effective upon installation and operation of the compressor engines and
generator engine. The Facility will continue to maintain compliance.
o Monitoring requirements including fuel consumed, catalyst temperature, catalyst pressure, and catalyst
and AFR presence will continue to be followed. Records of maintenance and test results will be kept
for a minimum of 5 years. Notifications and protocols for each scheduled test will be submitted at
least 30 days prior to the test date. Test reports for each conducted test will be submitted within 60
days of the test date.
IV. Subpart KKKK - Standards of Performance for Stationary Combustion Turbines
o The Facility is in compliance at the time of this application submittal. The turbine meets the emissions
standards of 40 CFR Part 60 Subpart KKKK by conducting performance tests following the appropriate
methods of the rule. The turbine was tested within 180 days of startup of the unit in December of
2023. The protocol and notification were submitted at least 30 days prior to the test and the test
report was submitted within 60 days of the test date. The amount of H 2S within the fuel is also
monitored to make sure the SO2 emissions standard is within compliance.
o These requirements were effective upon installation and operation of the turbine. The Facility will
continue to maintain compliance.
o Monitoring requirements including fuel consumed and SoLoNOx presence will continue to be
followed. Records of maintenance and test results will be kept for a minimum of 5 years. Notifications
and protocols for each scheduled test will be submitted at least 30 days prior to the test date. Test
reports for each conducted test will be submitted within 60 days of the test date.
40 CFR Part 63 – National Emission Standards for Hazardous Air Pollutants for Source Categories
I. Subpart ZZZZ – National Emissions Standards for HAPs for Stationary Reciprocating Internal Combustion
Engines (RICE)
o The Facility is in compliance at the time of this application submittal. The Facility is still classified as
an area source of HAPs (see Appendix D) and therefore meets the requirements of this rule by
following 40 CFR Part 60 Subpart IIII and 40 CFR Part 60 Subpart JJJJ.
o These requirements were effective upon installation and operation of the compressor engines, turbine,
and generator engines. The Facility will continue to maintain compliance.
o Monitoring and recordkeeping requirements include documenting the Facility is and continues to be
an area source of HAPs. Other monitoring, recordkeeping, testing, and reporting requirements are
found in 40 CFR Part 60 Subpart IIII and 40 CFR Part 60 Subpart JJJJ.
Based on the installed and operational equipment at the facility, 40 CFR Part 63 Subparts A and HH currently
do not apply to the Facility. The subject equipment would be the permitted EG dehydrators. Since this
equipment and associated processes are not current emission units subject to emissions standards at the
Facility, Subparts A and HH does not apply to the Facility.
Approval Order
Section 1: General Provisions
I.1. Definition, terms, abbreviations, and references
o The Facility is in compliance at the time of this application submittal. The definitions, terms,
abbreviations, and references in the AO are identified and defined in Utah Administrative Code (UAC)
R307 and 40 Code of Federal Regulation (CFR).
o The requirement was effective upon approval of the AO. The Facility will continue to maintain
compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application.
1.2 Limit exceedance disallowed without prior approval
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. Monitoring,
testing, recordkeeping, and reporting conducted during the first year of operation noted no limit
exceedances at the Facility. Should a modification or new emissions unit be proposed for the Facility,
Crusoe will submit the application and meet the minimum requirements of a complete application for
UDAQ review including best available control technology (BACT).
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Crusoe demonstrated the equipment at the
Facility will operate through BACT. The Facility was constructed and operates as indicated in the
application submitted to UDAQ in September of 2022. Should any modifications be made to the
Facility, a NOI modification application will be submitted to UDAQ.
1.3 Modification review and approval
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility is permitted (see Approval Order compliance discussion) and met the
requirements for a permit through UDAQ review of its September 2022 NOI application. Monitoring,
testing, recordkeeping, and reporting conducted during the first year of operation noted no limit
exceedances at the Facility. Should a modification or new emissions unit be proposed for the Facility,
Crusoe will submit the application and meet the minimum requirements of a complete application for
UDAQ review including best available control technology (BACT).
o The requirement was effective prior to construction of the Facility. The Facility will continue to
maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Crusoe demonstrated the equipment at the
Facility will operate through BACT. The Facility was constructed and operates as indicated in the
application submitted to UDAQ in September of 2022. Should any modifications be made to the facility,
a NOI modification application will be submitted to UDAQ.
I.4 Records retention and review by UDAQ
o The Facility is in compliance at the time of this application submittal. Records kept as part of the AO
or other state, or federal regulations are stored electronically and are available to UDAQ upon request
with adequate time to gather and organize the data to fulfill the records request.
o The requirement was effective upon construction and startup of the Facility. The Facility will continue
to maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Records will kept for at least two years, but
many will be for at least five years.
I.5 Good air pollution control practices for minimizing emissions
o The Facility is in compliance at the time of this application submittal. The equipment installed and
operational at the Facility are operated in a manner consistent with good air pollution control practice
for minimizing emissions by following manufacturer operating and maintenance procedures for the
emissions units and control equipment.
o The requirement was effective upon installation and startup of the Facility. The Facility will continue
to maintain compliance.
o No additional monitoring, testing, recordkeeping, or reporting is required due to the current AO nor
because of this Title V Operating Permit Application. Monitoring conducted as elsewhere required in
the AO or by federal regulation is conducted at required intervals. Testing showing emissions limits
are met is conducted at frequencies required by the AO or by federal regulation. UDAQ was onsite
during October 2023 to witness a stack test to inspect the Facility.
I.6 Breakdown requirements
o The Facility is in compliance at the time of this application submittal. No breakdowns occurred during
the first year of operation. Should an unavoidable breakdown occur in the future, the Facility will
continue to comply with the breakdown requirements where emission limitations and visible emission
limitations are exceeded for only as short a period of time as reasonable. The owner or operator shall
take all reasonable measures to limit the total emissions from the source.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring, including duration of breakdown, any visible emissions, and measures to minimize
emissions, will be conducted. Records of each breakdown will be kept and reported to UDAQ, as
required.
I.7 Emission inventory requirements
o The Facility is in compliance at the time of this application submittal. The 2023 emissions inventory
was submitted to UDAQ prior to the April 15, 2024, deadline. The Facility will continue to comply
with the emissions inventory requirements for future calendar years.
o The requirement was effective starting January 1, 2024. The Facility will continue to maintain
compliance and keep records of the submitted emissions inventory and back-up calculations, data,
measurements, and estimates used.
o Emissions calculation records will be kept for each emissions inventory submittal. Data monitored
during the calendar year including fuel consumed, fuel gas specification such as H 2S concentrations and
heat value, and stack test results will be recorded, as needed, but at least annually to conduct the
emissions inventory. Reports will be submitted by April 15th of each year.
I.8 Construction timeline and notification requirements
o The Facility is in compliance at the time of this application submittal. The notification of startup of
the compressor engines, turbine, and generator engines were submitted in June and August of 2023
following the installation and startup of the emissions units. These dates are within 18 months of the
AO approval in February 2023. The EG dehydrators, reboilers, and bullet tanks have not been
constructed to date. Notification will be provided to UDAQ if these emission sources are not installed
by August 2024 (18 months following AO approval).
o The requirement was effective upon AO approval. The Facility will continue to maintain compliance.
o Crusoe will submit notification of the construction status of the emissions sources not yet installed at
the Facility no later than August 2024. Crusoe submitted the appropriate notifications in June and
August of 2023 for the permitted emissions units that have begun operation.
Section I1: Permitted Equipment
II.A. Approved Equipment
o The Facility is in compliance at the time of this application submittal. The two compressor engines
have a maximum horsepower rating of 530, are each fueled by natural gas, and each fitted with a NSCR.
As indicated above, these compressor engines are subject to 40 CFR Part 60 Subpart JJJJ and 40 CFR
Part 63 Subpart ZZZZ. The ten generator engines have a maximum horsepower rating of 2500, are
each fueled by natural gas, and each fitted with a NSCR. As indicated above, these generator engines
are subject to 40 CFR Part 60 Subpart JJJJ and 40 CFR Part 63 Subpart ZZZZ. The turbine has a
maximum power rating of 13,364 kilowatts, is fueled by natural gas, and is built with a SoLoNOx
control. As indicated above, the turbine is subject to 40 CFR Part 60 Subpart KKKK. The two
emergency generator engines are each rated at 2,000 kilowatts, will be fueled by diesel, and are
certified to Tier 4 emissions standards. As indicated above, the emergency generator engines are
subject to 40 CFR Part 60 Subpart IIII and 40 CFR Part 63 Subpart ZZZZ. No other equipment in this
section is installed or operational at the Facility.
o The requirement was effective upon construction of the Facility. The Facility will continue to maintain
compliance.
o Crusoe will submit notification of the construction status of the emissions sources not yet installed at
the Facility no later than August 2024. Crusoe submitted the appropriate notifications in June and
August of 2023 for the permitted emissions units that have begun operation. Should any modifications
be necessary for the approved equipment, a NOI modification will be submitted to UDAQ prior to
implementation.
II.B.1.a Visible Emissions of Natural Gas-Fired Engines and Turbines
o The Facility is in compliance at the time of this application submittal. Regular visible emissions checks
are conducted to ensure no visible emissions to ensure the 10% opacity limit is not exceeded. The
Facility will continue to comply with the visible emissions standards.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring of visible emissions checks will be done regularly using either Method 9 to measure opacity
or Method 22 to determine if visible emissions occur. Records of visible emissions checks will continue
to be kept for the combustion equipment. Any corrective actions following visible emissions checks
will be kept and reports will be submitted, if required.
II.B.1.b Fuel Requirements for Natural Gas-Fired Engines and Turbines
o The Facility is in compliance at the time of this application submittal. The fuel sent to the Facility is
from surrounding oil and gas facilities and is natural gas. The estimated heat content of the field gas is
between 1,300 and 1,400 British thermal units per standard cubic feet (Btu/scf). No more than 25 ppm
hydrogen sulfide (H2S) is expected in the field gas.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring of the inlet gas will continue to be conducted to make sure only field gas or natural gas is
consumed by the compressor engines, turbine, and generator engines. Records of fuel specifications
will be kept, as required.
II.B.1.b Control Devices for Natural Gas-Fired Engines
o The Facility is in compliance at the time of this application submittal. Each compressor engine and
generator engine are fitted with a NSCR and AFR in order to achieve the emissions limits set forth in
this AO and as required by federal regulations.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
o Monitoring for the presence of the NSCR on each compressor engine and generator engine will
continue to be conducted. Regular maintenance on the NSCRs will be conducted, as required by
manufacturer specifications.
II.B.2 Emissions Limits and Stack Test Requirements of Natural Gas-Fired Engines and Turbines.
o The Facility is in compliance at the time of this application submittal. The initial tests for the two
compressor engines, one turbine, and ten generator engines were conducted in quarter 4 (from
October through December 2023) within 180 days of the startup of the emissions unit. Each
engine demonstrated compliance with the emissions limits of the AO via stack testing
Emissions Unit Serial
Number
Test Due
Date
Notification &
Protocol
Submittal Date
Test
Date
Report
Submittal
Date
10/24/20239/19/202312/9/20231469776Generator Engine 12/12/2023
10/25/20239/19/202312/10/20231457259Generator Engine 12/12/2023
10/26/20239/19/202312/11/20231632554Generator Engine 12/12/2023
10/27/20239/19/202312/15/20231453999Generator Engine 12/12/2023
11/13/202310/12/202312/6/20231650569Generator Engine 12/12/2023
11/14/202310/12/202312/7/20231650560Generator Engine 12/12/2023
11/15/202310/12/202312/9/20231650541Generator Engine 12/12/2023
11/16/202310/12/202312/12/20231650581Generator Engine 12/12/2023
11/20/202310/12/202312/14/20231650576Generator Engine 12/12/2023
11/21/202310/12/202312/13/20231658729Generator Engine 12/12/2023
12/22/202311/20/20231/19/2024KG14856Turbine 1/8/2024
Compressor Engine 12/20/202311/20/20231/19/20243221509 1/8/2024
Compressor Engine 12/21/202311/20/20231/19/20241663358 1/8/2024
II.B.3.a Visible Emissions of Diesel-Fired Emergency Engine Generator Set Requirements
o The Facility is in compliance at the time of this application submittal. At the time of this submittal,
the emergency diesel generator engines were not operated and thus did not exceed opacity
requirements.
o The requirement is effective upon startup. At the time of this submittal, the emergency diesel generator
engines were not operated and thus did not exceed opacity requirements. The Facility will continue
to maintain compliance.
o Monitoring of visible emissions checks will be done regularly using either Method 9 to measure opacity
or Method 22 to determine if visible emissions occur. Records of visible emissions checks will continue
following the appropriate methods and standard conditions outlined in Condition II.B.2.c. The
notification, protocol,and report submittal dates were within the requirements of II.B.2.b and are
tabled below. The tests were conducted in accordance with the submitted test protocols. During
the October stack test, a representative from UDAQ conducted a site inspection with OSHA
approved access to the test location.
o The requirement was effective since startup. The Facility will continue to maintain compliance.
Subsequent performance tests will be conducted annually.
o Testing to demonstrate compliance with the NOx, CO, and VOC emissions limits will be conducted
annually following the initial test conducted as demonstrated in the table below. Test methods and
standard condition constants approved by EPA and included in submitted and approved protocols will
be followed for subsequent performance tests which will include test duration. Reports including the
notification, protocol, and test results will continue to be submitted within the appropriate timelines.
to be kept for the combustion equipment. Any corrective actions following visible emissions checks
will be kept and reports will be submitted, if required.
II.B.3.b&c Operational Requirements of Diesel-Fired Emergency Engine Generator Set Requirements
o The Facility is in compliance at the time of this application submittal. At the time of this submittal,
the emergency diesel generator engines have not operated and thus not exceeded the hours limit for
maintenance checks and readiness testing, non-emergency situations, or maintenance and testing.
o The requirement is effective upon startup. At the time of this submittal, the emergency diesel generator
engines were not operated and thus did not exceed the hour limits. The Facility will continue to
maintain compliance.
o Monitoring of hours the emergency diesel generator engines operate will be kept. Records of the date
the emergency engine was used, the duration of operation, and the reason for operation will be kept.
Hours of operation will be monitored with a non-resettable hour meter.
II.B.3.d Emissions Standards of Diesel-Fired Emergency Engine Generator Set Requirements
o The Facility is in compliance at the time of this application submittal. The emergency diesel generator
engines were purchased as certified emissions units to Tier 4 emissions standards. The certified
emissions rate is a maximum 0.5 grams per horsepower hour of NOx. At the time of this submittal,
the emergency diesel generator engines were not operated and thus did not exceed the emissions
standards.
o The requirement is effective upon startup. At the time of this submittal, the emergency diesel generator
engines had not operated and thus did not exceed emissions standards. The Facility will continue to
maintain compliance.
o When the emergency diesel generator engines operate, monitoring and maintenance of the units will
be conducted in adherence to manufacturer and certification procedures. Records of the certification,
maintenance, and manufacturer specifications will be kept.
II.B.3.e&f Fuel requirements of Diesel-Fired Emergency Engine Generator Set Requirements
o The Facility is in compliance at the time of this application submittal. At the time of this submittal,
the emergency diesel generator engines have not operated. Fuel purchased for the Facility will be
ULSD meaning no more than fifteen parts per million of sulfur.
o The requirement is effective upon startup. At the time of this submittal, the emergency diesel generator
engines have not operated. The Facility will continue to maintain compliance.
o When the emergency diesel generator engines operate, fuel purchased will be ULSD with no more
than fifteen parts per million of sulfur will be kept. Records of the purchased fuel will be maintained
via invoices or supplier certification.
II.B.4 Monitoring Requirement of Fugitive Emissions (Leak Detection and repair)
These requirements are not applicable as the subject equipment to the leak detection and repair requirements
is not installed or operational.