DAQ-2025-001376

1

DAQC-241-25
Site ID 16140 (B4)

MEMORANDUM

TO: STACK TEST FILE – CRUSOE ENERGY SYSTEMS, INC. – Mullins Tap Facility

THROUGH: Rik Ombach, Minor Source Oil and Gas Compliance Section Manager

FROM: Paul Bushman, Environmental Scientist

DATE: March 3, 2025

SUBJECT: Sources: Five (5) Waukesha 9394 GSI generator engines; Unit IDs: 1320, 1454,
2026-01, 1452, 1453
Location: Duchesne County, UT
Contact: Kaitlin Meszaros: 631-245-0308.
Tester: Great Plains Analytical Services, Inc.
Site ID #: 16140
Permit/AO #: DAQE-AN161400001-23, dated August 9, 2023
Subject: Review of Pretest Protocol dated February 28, 2025

On February 28, 2025, Utah Division of Air Quality (DAQ) received the protocol for the testing of five
(5) Waukesha 9394 GSI generator engines at Crusoe Energy Systems, Incorporated Mullins Tap Facility
in Duchesne County, UT. Testing will be performed during the week of March 31, 2025, to determine
compliance with the emission limits found in Condition II.B.2 of Approval Order
DAQE-AN161400001-23 and 40 CFR Part 60 Subpart JJJJ.

PROTOCOL CONDITIONS:

1. RM 1 used to determine sample velocity traverses: OK
2. RM 2 used to determine stack gas velocity and volumetric flow rate: OK
3. RM 3A used to determine dry molecular weight of the gas stream: OK
4. ASTM D6348-03 used to determine H2O content; NOx, CO, and VOC emissions: OK

DEVIATIONS: None.

CONCLUSION: The protocol appears to be acceptable.

RECOMMENDATION: Send protocol review and test date confirmation notice.

ATTACHMENTS: Crusoe Energy Systems’ pretest protocol and test notification.
303 West 3rd Street ● Elk City, Oklahoma 73644 ● 580-225-0403

GAS Inc.
www.gasinc.us
February 28, 2025

Utah Department of Environmental Quality
State Office Building – Air Quality Division
195 North 1950 West
Salt Lake City, Utah 84114

RE: Crusoe Energy Systems, Inc.
40 CFR Part 60 Subpart JJJJ – Test Notification

To Whom It May Concern,

We are notifying you of performance testing dates for 40 CFR Part 60, Subpart JJJJ on behalf of
Crusoe Energy Systems, Inc. Please see below for the information pertinent to the testing. The
testing will take place the week of March 31, 2025.

Facility Unit # Serial # Location
Crusoe Mullins Tap Facility 1320 WAU -1632087 Duchesne County, Utah
Crusoe Mullins Tap Facility 1454 WAU -1651084 Duchesne County, Utah
Crusoe Mullins Tap Facility 2026-01 WAU -1641324 Duchesne County, Utah
Crusoe Mullins Tap Facility 1452 WAU -1651044 Duchesne County, Utah
Crusoe Mullins Tap Facility 1453 WAU -1651075 Duchesne County, Utah

Our testing protocol is included, for information regarding our protocol or the performance test,
you can contact me by email at [e-mail] or by phone at 580-225-0403. For
information regarding engine or location information, please contact Kaitlin Meszaros by email
at [e-mail] or by phone at (631)-245-0308.

Regards,

Macie Holsapple
Client Services Supervisor
GAS Inc.
Great Plains Analytical Services, Inc.
TypeAnnual
Prepared on behalf ofCrusoe Energy Systems, Inc.
Unit IDs
1320, 1454, 2026-01, 1452, 1453
Prepared by
303 West 3rd StreetElk City, OK 73644
Performance Test Protocol40 CFR Part 60 Subpart JJJJ
Facility: Crusoe Mullins Tap Facility
State of Utah
Permit ID: #DAQE-AN161400001-23
Great Plains Analytical Services, Inc.
1.0 Introduction………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….3
1.1 Contact Information………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….3
2.0 Test Information………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….3
3.0 Method Synopsis………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….5
4.0 Emission Point Information………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….6
4.1 Target Analytes………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….6
4.2 Test Quality Objectives………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….6
5.0 Quality Control Information………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….7
6.0 Additional Information and Reporting………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….8
7.0 Example Calculations………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….8
8.0 Health and Safety Concerns………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….9
1.1 Contact Information………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….3
2.0 Source Information and Testing Dates………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….3
2.1 Testing Limits and Parameters (Federal)………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….4
2.2 Testing Limits and Parameters (State)………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….4
2.3 Additional Parameters………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….4
4.2 Test Specific Target Analytes and Data Quality Objectives………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….6
5.0 QA/QC………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….7
5.1 Measurement System Capabilities………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….7
3.1 Sample Port Location………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….5
3.2 Sample locations inside the stack………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….5
9.0 Sampling Schematic Diagram………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….9
10.0 Engine Parameter Data Sheet Diagram………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….10
11.0 Velocity Field Data Diagram………………………………………………………………………………………………………………………………………………………………………………………………….…………………………………………………………………………………………………….10
Table of Contents
Table(s)
Figure(s)
Protocol Attachment(s)
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Great Plains Analytical Services, Inc.
2.0 Test Information (continued)
2026-01
1452
1453
1320
1454 Week of
03/31/2025
WAU-1641324 Crusoe Mullins Tap
Facility
Waukesha 9394
GSI 2500Week of
03/31/2025
WAU-1651084 Crusoe Mullins Tap
Facility
Waukesha 9394
GSI 2500
GAS has been contracted by Crusoe Energy Systems, Inc. to conduct source testing services at Crusoe Mullins Tap Facility located in Duchesne County, Utah. The purpose of this test
plan is to document the test methods and procedures that will be employed to collect and analyze exhaust gas emissions during performance testing of the internal combustion engines
fueled by Natural Gas.
Contact
Macie Holsapple
Physical Address
303 W 3rd St. Elk City, OK 73644GAS580-225-0403
Table 1.1 Contact Information
Kaitlin Meszaros
Serial Number Location/Facility
Name Make and Model Site Rated
Horsepower
Application Telephone Email Address
Source ID
WAU-1632087 Crusoe Mullins Tap
Facility
Waukesha 9394
GSI 2500
Test Dates
Week of
03/31/2025
[e-mail]
Crusoe Energy
Systems, Inc.720-614-5598 [e-mail]
Table 2.0 Test Information and Testing Dates
WAU-1651044 Crusoe Mullins Tap
Facility
Waukesha 9394
GSI 2500Week of
03/31/2025
Waukesha 9394
GSI 2500Week of
03/31/2025
1.1 Contact Information
2.0 Test Information
WAU-1651075 Crusoe Mullins Tap
Facility
1.0 Introduction
Tests will consist of (3) 60 minute test runs.
The test will be conducted using a multi component gas analyzer that incorporates a Fourier Transform Infrared (FTIR) spectrometer. FTIR is state of the art technology. It is
designed to military specifications and allows simple calibration using only single component calibration gases.
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Great Plains Analytical Services, Inc.
g/hp-hr lb/hr TPY ppm
@15% O2 g/hp-hr lb/hr TPY ppm
@15% O2 g/hp-hr lb/hr TPY ppm
@15% O2
1.00 2.00 0.70
1.00 2.00 0.70
1.00 2.00 0.70
1.00 2.00 0.70
1.00 2.00 0.70
g/hp-hr lb/hr TPY ppm
@15% O2 g/hp-hr lb/hr TPY ppm
@15% O2 g/hp-hr lb/hr TPY ppm
@15% O2
0.15 0.83 0.30 1.65 0.03 0.170
0.15 0.83 0.30 1.65 0.03 0.170
0.15 0.83 0.30 1.65 0.03 0.170
0.15 0.83 0.30 1.65 0.03 0.170
0.15 0.83 0.30 1.65 0.03 0.170
3A
D6348-03
1/1A
1452
1453
1320
1454
2026-01
NOx CO Reference Method ASTM D6348-03Reference Method ASTM D6348-03
Table 2.1 Testing Limits and Parameters (Federal)
Reference Method ASTM D6348-03Source ID
VOC (NMNEHC)
Table 2.2 Testing Limits and Parameters (State)
Source ID
NOx CO VOC (NMNEHC)
Reference Method ASTM D6348-03 Reference Method ASTM D6348-03 Reference Method ASTM D6348-03
1320
1454
2026-01
1452
1453
CH2O
320
Reduction %
Table 2.4 Testing Limits and Parameters (Reduction)
1453
1320
1454
2026-01
1452
Source ID
Table 2.3 Additional Parameters
Reduction %
Reference Method 10/2
COOxygen (O2)%vd
Moisture % H2O
Sample Location Inches (")
CO2, H2O, NOx, CO, VOC, and CH2O will be
measured using a Gasmet multigas FTIR analyzer in
accordance with ASTM Method D6348 when
applicable analytes are being tested for.
Footnote
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Great Plains Analytical Services, Inc.
3.0 Method Synopsis
For all stacks greater than 6" in diameter, GAS will sample at 3 points within the stack. These points will be located at 83.3%, 50%, and 16.7% of the
stack diameter.
1/2 diameter upstream
2 diameters downstream
Figure 3.2. Sample locations inside the stack
Actual diameter
Figure 3.1. Sample Port Location
EPA Method 1/1A
Figure 3.1
Figure 3.2
The purpose of the method is to provide guidance for the selection of sampling ports and traverse points at which sampling for air pollutants will be
performed pursuant to regulations set forth in this part. Method 1 may be modified as allowed in Subpart JJJJ & ZZZZ. Alternatively, for NOx, CO,
VOC, O2, and moisture measurement, ducts ≤6 inches in diameter may be sampled at a single point located at the duct centroid and ducts >6 and
≤12 inches in diameter may be sampled at 3 traverse points located at 16.7, 50.0, and 83.3% of the measurement line ('3-point long line'). If the
duct is >12 inches in diameter and the sampling port location meets the two and half-diameter criterion of Section 11.1.1 of Method 1 of 40 CFR
part 60, Appendix A, the duct may be sampled at '3-point long line'; otherwise, conduct the stratification testing and select sampling points
according to Section 8.1.2 of Method 7E of 40 CFR part 60, Appendix A."
For all stacks greater than 6" in diameter, GAS will use a sampling port that is located at a minimum of 2 stack diameters downstream from any
disturbance, and 1/2 stack diameter upstream from any disturbance.
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Great Plains Analytical Services, Inc.
4.1 Target Analytes
4.2 Test Quality Objectives
EPA Method 2/2C
EPA Method 3A
This method is applicable for the determination of the average velocity and the volumetric flow rate of a gas stream. Method
2 will be used for stacks greater than 12 inches. Method 2C will be used for stacks with a diameter of 12 inches or less.
This is a procedure for measuring oxygen (O2) and carbon dioxide (CO2) in stationary source emissions using a continuous
instrumental analyzer. Quality assurance and quality control requirements are included to assure that the tester collects data
of known quality. Documentation to these specific requirements for equipment, supplies, sample collection and analysis,
calculations, and data analysis will be included.
NO 1875-2138 0-1000 ppm 0.20 ppm 2 ppm
ASTM D6348-03
This extractive FTIR based field test method is used to quantify gas phase concentrations of multiple target analytes from
stationary source effluent. Because an FTIR analyzer is potentially capable of analyzing hundreds of compounds, this test
method is not analyte or source specific. The analytes’ detection levels, and data quality objectives are expected to change
for any particular testing situation. It is the responsibility of the tester to define the target analytes, the associated detection
limits for those analytes in the particular source effluent, and the required data quality objectives for each specific test
program. Provisions are included in this test method that require the tester to determine critical sampling system and
instrument operational parameters, and for the conduct of QA/QC procedures. Testers following this test method will
generate data that will allow an independent observer to verify the valid collection, identification, and quantification of the
subject target analytes. A heated sample line is used to collect the sample on a wet basis per ASTM D6348. Effluent
Moisture content is determined to within a 2% accuracy using the FTIR analytical algorithm.
4.0 Emissions Point Information
4 ppm1 ppm0-1200 ppm2000-2200
2700-2950 0-100 ppm 0.03 ppm 2 ppmNO2
*. Measured flue gas conditions at the sampling location including temperature, moisture content, and volumetric flow rate
will be included in test results.
Interfering CompoundsCO2 926-1150 0-10%0%n/aWater Vapor 3200-3401 0-22%0.2%n/a
VOC as defined in 40 CFR Part 60
subpart JJJJ
2600-3200
0-100 ppm 0.9 ppm 1 ppm910-11502550-2950
Section 12.5 of this method will be utilized to determine the molecular weight of the stack on a wet basis. The formula found
in Method 3 section 12.3 will be utilized to determine the molecular weight of the stack gas on a dry basis.
CO
Target Analytes
Exhaust emission testing will be conducted for the following compounds: carbon monoxide (CO), oxides of nitrogen (NOx),
volatile organic compounds (VOCs), and oxygen (O2%).
Table 4.2 summarizes the test quality objectives specific that will be used to evaluate test data to a known degree of
accuracy.
Compounds
Table 4.2. Test Specific Target Analytes and Data Quality Objectives
Infrared Analysis
Expected
Concentration Range
Measurement
System Achievable
Minimum Detectable
Concentrations
Required
Measurement
System Accuracy
and Precision for
Test Application
(cm-1)
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Great Plains Analytical Services, Inc.
Path
Length
Dilution
Factor
%
Recovery
4.93
10 92
A1)
A2)A3)A4)A5)A6)A7)
Stainless Steel Every Test
Velocity Flow Measurement
(2)
Manometer is leveled and visual
inspected
Sample Point Selection (1/1A)1/2 stack diameter downstream and 2
stack diameters upstream.Every test
Sample Extraction (D6348)Placed after heated probe Changed weekly
Heated to 180°C, introduces calibration
into sampling system at the probe outlet Every testProbe Box
Sample Extraction (3A/D6348)Sample kept above dew point at all
times.
Temp kept to 180°C at
all times. Visible
digital gaugeSample Extraction (1/1A)
Every test run
Manometer
Manometer
Velocity Flow Measurement
(2)
System is back purged after last sample.
Another sample is taken and must be
within 5% of the last sample
Every test
System Performance (D6348)
Verify line positions have not shifted by
more than 15% of the resolution, and the
resolution has not changed by more than
15% of that determined prior to testing.
Post TestLine position
System Performance (3A)Within 5%Before first test and
after last
Calibration
System bias check
System Performance (D6348)Within Tolerance Pre and post test
System Zero
CTS Check direct to analyzer
System Performance (D6348)Within Tolerance Pre Test
System Performance (D6348)Within 30% of effluent concentration Every test run
System Performance (3A)Within 10% of the Sample collected Every test
5.0 Quality Control Information
The following is a list of the QA/QC procedures performed. It is listed as to the process and method it pertains
to. Calibration sheets, calibration gases and any other testing equipment will be made available prior to the
start of testing. Upon completion of the assembled sampling system, a leak check will be conducted under
pressure or partial vacuum conditions to ensure the integrity of the sample collection system.
QA/QC Element
Traceability protocol
Probe material
Particulate filter
Table 5.0 QA/QC
Multiple Sample Points
Simultaneously (1/1A)83.3%, 50%, 16.6% from stack walls All stacks under 6"
Measurement from disturbances
Distance from stack walls
Sample Extraction (D6348)
Heated line
Manifold material
Process or Element
(Method)Acceptance Criteria Frequency
Calibration Gas 2% Certainty Every Test
Sample Extraction (1/1A)Pass system bias check Every test run
Propane 101.9 37
Table 5.1. Measurement System Capabilities
Parameter Measured Gas Concentration Equilibration Time
Path Length Ethylene 101.2
Analyte Spike Recovery Propane 101.9 50
CTS Check entire system
System Recovery (Spike)
Data generated during the bench scale pre-test procedures will be presented in Table 5.1. Please note that Table 5.1 will
be presented in the final report with data collected from the actual field-testing source.
System Performance
(3A/D6348)Determines minimum sampling time During bias check
System Performance (3A)Within 3%During bias check
System response time
Drift
System Performance (D6348)Less than 2 % of permit limit Pre test
5.0 Quality Control Information (continued)
Mechanical Response Time Ethylene 101.2 42
System Response Time
Determination of System Performance Parameters - Noise Equivalent Absorbance, Line Position, Resolution, and Analyte Spiking TechniqueRequired Pre-Test ProceduresFTIR Reference Spectra
Preparation of Analytical Quantification Algorithm
Determination of FTIR Measurement System Minimum Detectable ConcentrationTest Plan Requirements
All information required per ASTM D6348, Annexes 1-7 will be provided in the final report. This information shall cover:
System Zero Nitrogen 65
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Great Plains Analytical Services, Inc.
* Elevation, Barometric pressure ("HG), Ambient temperature °F, Humidity %, Dew Point °F
* Catalyst Inlet Temp °F, Catalyst Outlet Temp °F, Manifold Temp °F
* Exhaust Gas Temp °C
* RPM, Manifold Pressure ("HG)
* Horsepower (BHP) and Fuel Flow Rate (dscfh)
* Stack Diameter (")
* Sample location (" Downstream from Disturbance & " Upstream from Disturbance)
* Catalyst Pressure Drop ( Inches H2O)
* Moisture Percentage
* Volumetric Flow Rate
* AFR setpoints and reading
* Catalyst Manufacturer
* Number of elements
* Date of installation
* Date of last reconditioning or cleaning
1. Exhaust Volumetric flow Rate Determination by EPA Method 2
Qsd=3600*(1-B(ws))*V(s)*A*(T(std)/T(s))*P(s)/P(std)
V(s)= Absolute Stack Gas Velocity
A= Cross Sectional Area of Stack
T(std)= Standard Absolute Temperature
T(s)= Absolute Stack Temperature
P(s)= Absolute Stack Pressure
P(std)= Standard Absolute Pressure
(When Method 2 is used)
K=Pitot tube velocity Constant (85.49)
C=Velocity Pressure Coefficient
√ΔP= Square Root of differential Pressure of stack gas (inH2O)
T(s(avg))= Average Stack temp °R
M=Molecular Weight of stack gas, wet basis
P= Absolute stack gas Pressure
3. Mass Emission Rates (G./HP.-HR.)
K*C*√(ΔP)*√(T(s(avg))+460)/√(M*P)V(s)=
6.0 Additional Information and Reporting
Additional parameters and atmospheric information will also be provided in the final report and will include:
The final report will contain all field test data including all pre and post calibration information. Final
concentrations will be reported in the permitted units of measure.
7.0 Example Calculations
2. Absolute Stack Gas Velocity V(s)
3. Mass Emission Rates (LBS./HR.)
((Mol Wgt)*(Qd dscfh)*(concentration (385*106)(LB/HR)*454Engine Horsepower
(LB/HR)*24(HRS/DAY)*365(Days/YR)2000(LB/TON)
3. Mass Emission Rates (TPY)
TPY =
g/hp-hr = lb/hr =
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Great Plains Analytical Services, Inc.
* Hardhat* Steel-Toed Boots* Safety Glasses* Hearing Protection* Fire-Retardant Clothing* 4 - Safety Gloves* 4 Gas Monitor
*
*
*
*
*
*
*
*
*
Control Panel: Allows the control of flow throughout the system as required by ASTM D6348 and
Method 3A. Allows for introduction of calibration standards into the sampling system at the probe
outlet, upstream of the primary particulate filter.
Due to the remote location of the source unit, additional health & safety precautions will be observed such as
avoidance of slips, trips, falls, and heat exhaustion.
Figure 9.0 Sampling Schematic Diagram
Figure 9.0 Schematic Diagram
In addition, GAS will use the following safety equipment:
O2 Sensor: Zirconium Dioxide sensor to measure Oxygen per method 3A.
Gasmet FTIR: FTIR Analyzer for use with ASTM D6348
Flow Meter: Allows proper measurement of flow.
Data: Data acquisition system that allows for the acquisition of the infrared data, Oxygen data and
analysis of the resulting spectra.
Gas: Required calibration gases per ASTM D6348 and Method 3A.
8.0 Health and Safety Concerns
In accordance with 40 CFR Part 60.8, the client must provide safe access to the unit for testing and observance.
Due to the nature of the source and the exposure to high temperatures, extreme caution will be observed in
order to avoid contact with the unit which may result in burns and or inhalation of exhaust emissions. GAS
personnel will sign in and out at all facilities, as well as undergo site specific safety training.
Probe: Heated probe assembly required by ASTM D6348.
Heated Line: Used for "Hot/Wet" sample to keep line above any dew point that would cause
moisture to drop out.PSS: Allows precise heating of the sampling system.
Breakdown Of Schematic Diagram:
!
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Great Plains Analytical Services, Inc.
**Note: Actual note parameters may differ due to the availability of such parameters at specific locations.
Attachment 10.0 Engine Parameter Data Sheet Diagram
Attachment 11.0 Velocity Field Data
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Great Plains Analytical Services, Inc.
10.0 Engine Parameter Data Sheet
Company
Facility
Date
Elevation (ft)
Unit ID
Make
Model
Serial Number
Technician
Run 1 Run 2 Run 3 AverageTime:9:06 AM 10:17 AM 11:28 AM N/A
Engine Speed (RPM)1601 1600 1603 1601Engine Hours 10568 10569 10570 10571Catalyst (Yes or No)Yes Yes Yes YesCatalyst Manufacturer Murphy Murphy Murphy Murphy# of Catalyst installed 1 1 1 1Catalyst Element Installation date 7/22/16 7/22/16 7/22/16 7/22/16Catalyst Inlet Temp °F 847 845 846 846Catalyst Outlet Temp °F 878 879 780 846Catalyst Pressure Drop H2O 1.50 1.50 1.50 1.50Catalyst reconditioning or cleaning date New New New NewAFR Manufacturer/Type Murphy Murphy Murphy MurphyAFR Setting (Targets Right Bank)17.00 17.00 17.00 17.00AFR Readings NA NA NA NA
Intake Manifold Pressure (psi)4.40 4.50 4.50 4.47Ambient Temp °F 76.00 79.00 83.00 79.33Exhaust Gas Temp °F (From Probe)785.00 784.00 783.00 784.00Intake Manifold Temp °F 85.00 85.00 85.00 85.00Barometric Press ("HG)30.13 30.13 30.11 30.12Fuel Flow Rate (dscf)587.00 586.63 587.73 587.12Engine Load (BHP)72.05 72.00 72.14 72.06
Cottonwood 08E
Cummins
4,724
Whiting Oil & Gas Company
7/26/2016
73697207
ENG-01
5.9
Noel Arnim