DAQ-2024-008305

1

DAQC-528-24
Site ID 10120 (B4)

MEMORANDUM

TO: STACK TEST FILE – BOUNTIFUL CITY LIGHT AND POWER – Power Plant

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

FROM: Kyle Greenberg, Environmental Scientist

DATE: May 31, 2024

SUBJECT: Source: GT 1, GT 2, and GT 3
Location: 253 South 200 West, Bountiful, Davis County, Utah
Contact: Kirk Cloward: 801-298-6088
Tester: American Environmental Testing Company Inc.
Site ID #: 10120
Permit/AO #: DAQE-AN101200006-18, dated July 16, 2018
Subject: Review of Pretest Protocol dated May 23, 2024

On May 23, 2024, Utah Division of Air Quality (DAQ) received a protocol for the testing of GT #1,
GT #2, and GT #3 at the Bountiful City Light and Power, Power Plant in Davis County, Utah. Testing
will be performed on August 6-9, 2024, to determine compliance with the emission limits found in
Condition II.B.2 of DAQE-AN101200006-18, and 40 CFR Part 60 Subparts GG and KKKK.

PROTOCOL CONDITIONS:

1. Method 1 used to determine sample traverses: OK
2. Method 2 used to determine stack gas velocity and volumetric flow rate: OK
3. Method 3A used to determine O2 and CO2 concentrations of the gas stream: OK
4. Method 4 used to determine moisture content: OK
5. Method 7E used to determine NOx emissions: OK
6. Method 9 used to determine visible emission opacity: OK
7. Method 10 used to determine CO emissions: OK
8. Method 20 used to determine testing parameters for emissions from gas turbines: OK

DEVIATIONS: None.

CONCLUSION: The methods proposed in the pretest protocol are acceptable to determine
the emission rates of NOx, CO, and visible emission opacities of the three
gas turbines.

2

RECOMMENDATION: It is recommended that the methods proposed in this pretest protocol be
considered as acceptable for determining NOx and CO emission limits
and visible emission opacities for the three gas turbines at Bountiful City
Light and Power, Power Plant.

ATTACHMENTS: Bountiful City Light and Power Testing Date Notification Letter and
Pretest Protocol
Source Test Plan
2024 Compliance Testing – NO X, CO, and VEOs
Bountiful City Light and Power
One (1) Solar Taurus 60 Gas Turbine (GT #1)
Two (2) Solar Titan 130 Gas Turbines
(GT #2 and GT #3)
Bountiful, Utah
Prepared For:
Bountiful City Light and Power
195 West 200 South
Bountiful, Utah 84010
Prepared By:
Montrose Air Quality Services, LLC
6823 South 3600 West
Spanish Fork, Utah 84660
For Submission To:
State of Utah Department of Environmental Quality
Division of Air Quality
195 North 1950 West
Salt Lake City, Utah 84114-4820
Document Number: GP081AS-041933-PP-861
Proposed Test Dates: August 6-9, 2024
Submittal Date: May 23, 2024
Bountiful City Light and Power
2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah
Review and Certification
I certify that, to the best of my knowledge, the information contained in this document is
complete and accurate and conforms to the requirements of the Montrose Quality
Management System and ASTM D7036-04.
Signature: Date:May 23, 2024
Name: Cheyney Guymon Title: Field Project Manager
I have reviewed, technically and editorially, details and other appropriate written materials
contained herein. I hereby certify that to the best of my knowledge the presented material
is authentic and accurate and conforms to the requirements of the Montrose Quality
Management System and ASTM D7036-04.
Signature: Date: May 23, 2024
Name: Joby Dunmire Title: QA/QC Specialist
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Table of Contents
Section Page
1.0 Introduction ........................................................................................................ 5
1.1 Summary of Test Program.............................................................................5
1.2 Applicable Regulations and Emission Limits......................................................6
1.3 Key Personnel..............................................................................................7
2.0 Plant and Sampling Location Descriptions................................................................ 8
2.1 Process Description, Operation, and Control Equipment ..................................... 8
2.2 Flue Gas Sampling Locations .......................................................................... 9
2.3 Operating Conditions and Process Data ........................................................... 9
2.4 Plant Safety ............................................................................................... 10
2.4.1 Safety Responsibilities ........................................................................ 10
2.4.2 Safety Program and Requirements ....................................................... 11
3.0 Sampling and Analytical Procedures ..................................................................... 12
3.1 Test Methods ............................................................................................. 12
3.2 Process Test Methods .................................................................................. 15
4.0 Quality Assurance and Reporting .......................................................................... 15
4.1 QA Audits .................................................................................................. 15
4.2 Quality Control Procedures .......................................................................... 15
4.2.1 Equipment Inspection and Maintenance ................................................ 16
4.2.2 Audit Samples ................................................................................... 16
4.3 Data Analysis and Validation ........................................................................ 16
4.4 Sample Identification and Custody ................................................................ 16
4.5 Quality Statement ...................................................................................... 17
4.6 Reporting ..................................................................................................17
4.6.1 Example Report Format......................................................................17
4.6.2 Example Presentation of Test Results ................................................... 19
List of Appendices
Appendix A Supporting Information ........................................................................... 20
Appendix A.1 Units and Abbreviations .................................................................. 21
Appendix A.2 Accreditation Information/Certifications ............................................ 22
Appendix A.3 Approval Order DAQE-AN101200006-18 ........................................... 33
Appendix “S” Field Work Safety Plan .......................................................................... 42
List of Tables
Table 1-1 Summary of Test Program and Proposed Schedule .......................................... 6
Table 1-2 .................................................................................................................. 6
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Reporting Units and Emission Limits for GT #1 (5.3 MW Solar Taurus 60 Turbine) .............. 6
Table 1-3 Reporting Units and Emission Limits for GTs #2 & #3 (13.5 MW Solar Titan 130
Turbines) ............................................................................................................ 7
Table 1-4 Test Personnel and Responsibilities ...............................................................8
Table 2-1 Sampling Locations .....................................................................................9
Table 4-1 Example Emissions Results - Turbine, Bountiful City Light and Power, Bountiful,
Utah ................................................................................................................. 19
List of Figures
Figure 4-1 Typical Report Format ..............................................................................18
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1.0 Introduction
1.1 Summary of Test Program
Bountiful City Light and Power contracted Montrose Air Quality Services, LLC (Montrose) to
perform a test program at their facility located in Bountiful, Utah.
The tests are conducted to determine compliance with the emission limits listed in Approval
Order (AO) DAQE-AN101200006-18, issued by the State of Utah Department of
Environmental Quality, Division of Air Quality on July 16, 2018. As part of the AO, the
UDEQ has required that emissions be verified annually. A copy of the AO is attached as
Appendix A-3.
The specific objectives are to:
Perform nitrogen oxides (NOX), carbon monoxide (CO), and visible opacity
of emissions (VEs) compliance testing on the exhaust of one (1) Solar
Taurus 60 natural gas-fired turbine (GT #1).
Perform NOX, CO, and VEs compliance testing on the exhausts of two (2)
Solar Titan 130 natural gas-fired turbines (GT #2 and GT #3).
Conduct the test program with a focus on safety
Montrose will provide the test personnel and the necessary equipment to measure emissions
as outlined in this test plan. Facility personnel will provide the process and production data
to be included in the final report. A summary of the test program and proposed schedule is
presented in Table 1-1.

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Table 1-1
Summary of Test Program and Proposed Schedule
Proposed
Test Date Unit ID Activity/Parameters Test Methods No. of Runs
Duration
(Minutes)
8/6/2024 GT #1 Flowrate, CO2,
H2O, NOX, CO, VEs
EPA M1, 2, 3A, 4,
7E, 91, 10, 20
3 @ each of 4
load conditions2 30/run
8/7/2024 GT #2
Flowrate, CO2,
H2O, NOX, CO, VEs
EPA M1, 2, 3A, 4,
7E, 91, 10, 20
3 @ normal
load condition3 30/run
8/8/2024 GT #3
1 Method 9 opacity observations per run are recorded every fifteen seconds during a six-minute
period.
2 Method 4 moisture determination runs will be one (1) run, forty-eight (48) minutes in duration for
each load condition
3 Method 4 moisture determination runs will be one (1) run, forty-eight (48) minutes in duration, for 3
runs at normal load condition
To simplify this test plan, a list of Units and Abbreviations is included in Appendix A.
Throughout this test plan, chemical nomenclature, acronyms, and reporting units are not
defined. Please refer to the list for specific details.
1.2 Applicable Regulations and Emission Limits
The results from this test program are presented in units consistent with those listed in the
applicable performance specifications. The reporting units and emission limits are presented
in Tables 1-2 and 1-3. Each turbine shall comply with the monitoring and testing
requirements of 40 CFR 60. Subpart GG, Sections 60.334 and 60.335 apply to GT #1.
Subpart KKKK, Sections 60.4335-4370 and Sections 60.4400-4415 apply to GT #2 and #3.
Table 1-2
Reporting Units and Emission Limits for GT #1 (5.3 MW Solar Taurus 60 Turbine)
Parameter Reporting Unit Emission Limit Emission Limit Reference
% % --
% % --
NOX g/kW-hr 0.6 Permit Condition II.B.2.d. CO 0.6
VEs % 10 Permit Condition II.B.1.b.

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Table 1-3
Reporting Units and Emission Limits for GTs #2 & #3 (13.5 MW Solar Titan 130
Turbines)
Parameter Reporting Unit Emission Limit Emission Limit Reference
% % --
% % --
NOX ppmvd@15% O2,
lb/hr
15,
7.5 Permit Condition II.B.2.d. CO
VEs % 10 Permit Condition II.B.1.b.
1.3 Key Personnel
A list of project participants is included below:

Facility Information
Source Location: Bountiful City Light and Power
195 West 200 South
Bountiful, Utah 84010
Project Contact: Kirk Cloward
Role: Plant Manager
Telephone: [phone]
Email: [e-mail]

Agency Information
Regulatory Agency: State of Utah DEQ, Division of Air Quality
Agency Contact: Chad Gilgen, Minor Source Compliance
Telephone: [phone]
Email: [e-mail]

Testing Company Information
Testing Firm: Montrose Air Quality Services, LLC
Contact: Beckie Hawkins Cheyney Guymon
Title: District Manager Field Project Manager
Telephone: [phone]
Email: [e-mail] [e-mail]

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Table 1-4 details the roles and responsibilities of the test team.
Table 1-4
Test Personnel and Responsibilities
Role Primary Assignment Additional Responsibilities
District Manager Coordinate project Post-test follow up
Field Project Manager Operate mobile lab Facility interface, test crew coordination
Technician Execute stack platform
responsibilities Preparation, support PM
2.0 Plant and Sampling Location Descriptions
2.1 Process Description, Operation, and Control
Equipment
A gas turbine is an internal combustion engine that operates with rotary rather than
reciprocating motion. Gas turbines are essentially composed of three major components:
compressor, combustor and power turbine. In the compressor section ambient air is drawn
in and compressed up to 30 times ambient pressure and directed to the combustor section
where fuel is introduced, ignited and burned. Combustors can either be annular, can-
annular or silo. An annular combustor is a doughnut-shaped, single, continuous chamber
that encircles the turbine in a plane perpendicular to the airflow. Can-annular combustors
are similar to the annular; however, they incorporate several can-shaped combustion
chambers rather than a single continuous chamber. Annular and can-annular combustors
are based on aircraft turbine technology and are typically used for smaller scale
applications. A silo (Frame-type) combustor has one or more combustion chambers
mounted external to the gas turbine body. Silo combustors are typically larger than annular
or can-annular combustors and are used for larger scale applications.
The combustion process in a gas turbine can be classified as diffusion combustion, or lean-
premix staged combustion. In the diffusion flame combustion, the fuel/air mixing and
combustion take place simultaneously in the primary combustion zone. This generates
regions of near-stoichiometric fuel/air mixtures where the temperatures are very high. For
lean-premix combustors, fuel and air are thoroughly mixed in an initial stage resulting in a
uniform, lean, unburned fuel/air mixture, which is delivered to a secondary stage where the
combustion reaction takes place. Manufacturers use different types of fuel/air staging,
including fuel staging, air staging, or both: however, the same staged, lean-premix principle
is applied. Gas turbines using staged combustion are also referred to as SoLoNOx
combustors. The majority of gas turbines currently manufactured are lean-premix staged
combustion turbines.
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Hot gases from the combustion section are diluted with additional air from the compressor
section and directed to the power turbine section at temperatures up to 2600°F. Energy
from the hot exhaust gases, which expand in the power turbine section, are recovered in
the form of shaft horsepower. More than 50 percent of the shaft horsepower is needed to
drive the internal compressor and the balance of the recovered shaft horsepower is
available to drive an external load. Gas turbines may have one, two, or three shafts to
transmit power between the inlet air compression turbine, the power turbine, and the
exhaust turbine. The heat content of the exhaust gases exiting the turbine can either be
discarded without heat recovery (single cycle); recovered with a heat exchanger to preheat
combustion air entering the combustor (regenerative cycle); recovered in a heat recovery
steam generator to raise process stream, with or without supplementary firing
(cogeneration); or recovered, with or without supplementary firing, to raise steam for a
steam turbine Rankine cycle (combined cycle or repowering).
2.2 Flue Gas Sampling Locations
Actual stack measurements, number of traverse points, and location of traverse points will
be evaluated in the field as part of the test program. Table 2-2 presents the anticipated
stack measurements and traverse points for the sampling locations listed.
Table 2-1
Sampling Locations
Sampling Location
Stack
Inside
Diameter
(in.)
Distance from Nearest
Disturbance
Number of Traverse
Points
Downstream
EPA “B”
(in./dia.)
Upstream EPA
“A” (in./dia.)
GT #1 (Solar Taurus
60 Turbine)57.0 300.0/5.26 58.0/1.01 Flow: 16 (12/port)
Gaseous: Single point or
3-point short lineGTs #2 and #3 (Solar
Titan Turbines)
78.0 370.0/4.74 106.0/1.36
Sample locations are verified in the field to conform to EPA Method 1. Acceptable cyclonic
flow conditions are confirmed prior to testing using EPA Method 1, Section 11.4.
2.3 Operating Conditions and Process Data
Emission tests are performed while the source/units and air pollution control devices are
operating at the conditions required by the permit. As defined by the permit, the production
rate during all compliance testing shall be no less than 90% of the maximum production
rate achieved in the previous three (3) years. GT #1 Solar Taurus 60 will be tested in
accordance with the requirements of 40 CFR Part 60 Subpart GG Section 60.335(b)(2). This
requires the turbine to be tested at four (4) loads spaced evenly in the normal operating
range.

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Plant personnel are responsible for establishing the test conditions and collecting all
applicable unit-operating data. Data collected includes the following parameters:
Unit Load (MW)
2.4 Plant Safety
Montrose will comply with all safety requirements at the facility. The facility Client Sponsor,
or designated point of contact, is responsible for ensuring routine compliance with plant
entry, health, and safety requirements. The Client Sponsor has the authority to impose or
waive facility restrictions. The Montrose test team leader has the authority to negotiate any
deviations from the facility restrictions with the Client Sponsor. Any deviations must be
documented.
2.4.1 Safety Responsibilities
Planning
Montrose must complete a field review with the Client Sponsor prior to the
project date. The purpose of the review is to develop a scope of work that
identifies the conditions, equipment, methods, and physical locations that will
be utilized along with any policies or procedures that will affect our work.
We must reach an agreement on the proper use of client emergency services
and ensure that proper response personnel are available, as needed.
The potential for chemical exposure and actions to be taken in case of
exposure must be communicated to Montrose. This information must include
expected concentrations of the chemicals and the equipment used to identify
the substances.
Montrose will provide a list of equipment being brought to the site, if required
by the client.
Project Day
Montrose personnel will arrive with the appropriate training and credentials
for the activities they will be performing and the equipment that they will
operate.
Our team will meet daily to review the Project Scope, Job Hazard Assessment,
and Work Permits. The Client Sponsor and Operations Team are invited to
participate.
Montrose will provide equipment that can interface with the client utilities
previously identified in the planning phase and only work with equipment that
our client has made ready and prepared for connection.
We will follow client direction regarding driving safety, safe work permitting,
staging of equipment, and other crafts or work in the area.
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As per 40 CFR Part 60 Subpart A, Section 60.8, the facility must provide the
following provisions at each sample location:
o Sampling ports, which meet EPA minimum requirements for testing. The
caps should be removed or be hand-tight.
o Safe sampling platforms.
o Safe access to the platforms and test ports, including any scaffolding or
man lifts.
o Sufficient utilities to perform all necessary testing.
Montrose will use the client communication system, as directed, in case of
plant or project emergency.
Any adverse conditions, unplanned shutdowns or other deviations to the
agreed scope and project plan must be reviewed with the Client Sponsor prior
to continuing work. This will include any safe work permit and hazard
assessment updates.
Completion
Montrose personnel will report any process concerns, incidents or near misses
to the Client Sponsor prior to leaving the site.
Montrose will clean up our work area to the same condition as it was prior to
our arrival.
We will ensure that all utilities, connection points or equipment have been
returned to the pre-project condition or as stated in the safe work permit. In
addition, we will walk out the job completion with Operations and the Client
Sponsor if required by the facility.
2.4.2 Safety Program and Requirements
Montrose has a comprehensive health and safety program that satisfies State and Federal
OSHA requirements. The program includes an Illness and Injury Prevention Program, site-
specific safety meetings, and training in safety awareness and procedures. The basic
elements include:
All regulatory required policies/procedures and training for OSHA, EPA and
FMCSA.
Medical monitoring, as necessary.
Use of Personal Protective Equipment (PPE) and chemical detection
equipment.
Hazard communication.
Pre-test and daily toolbox meetings.
Continued evaluation of work and potential hazards.
Near-miss and incident reporting procedures as required by Montrose and the
Client.
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Montrose will provide standard PPE to employees. The PPE will include but is not limited to;
hard hats, safety shoes, glasses with side shields or goggles, hearing protection, hand
protections, and fall protection. In addition, our trailers are equipped with four gas detectors
to ensure that workspace has no unexpected equipment leaks or other ambient hazards.
The detailed Site Safety Plan for this project is attached to this test plan in Appendix “S”.
3.0 Sampling and Analytical Procedures
3.1 Test Methods
The test methods for this test program have been presented in Table 1-1. Additional
information regarding specific applications or modifications to standard procedures is
presented below.
3.1.1 EPA Method 1, Sample and Velocity Traverses for Stationary
Sources
EPA Method 1 is used to assure that representative measurements of volumetric flow rate
are obtained by dividing the cross-section of the stack or duct into equal areas, and then
locating a traverse point within each of the equal areas. Acceptable sample locations must
be located at least two stack or duct equivalent diameters downstream from a flow
disturbance and one-half equivalent diameter upstream from a flow disturbance.
Pertinent information regarding the performance of the method is presented below:
No test method options or exceptions
3.1.2 EPA Method 2, Determination of Stack Gas Velocity and
Volumetric Flow Rate (Type S Pitot Tube)
EPA Method 2 is used to measure the gas velocity using an S-type pitot tube connected to a
pressure measurement device, and to measure the gas temperature using a calibrated
thermocouple connected to a thermocouple indicator. Typically, Type S (Stausscheibe) pitot
tubes conforming to the geometric specifications in the test method are used, along with an
inclined manometer. The measurements are made at traverse points specified by EPA
Method 1. The molecular weight of the gas stream is determined from independent
ture. The stack gas volumetric flow rate is calculated
using the measured average velocity head, the area of the duct at the measurement plane,
the measured average temperature, the measured duct static pressure, the molecular
weight of the gas stream, and the measured moisture.
Pertinent information regarding the performance of the method is presented below:
Method Options:
o S-type pitot tube coefficient is 0.84
o Shortridge multimeter may be used to measure velocity
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3.1.3 EPA Method 4, Determination of Moisture Content in Stack Gas
EPA Method 4 is a manual, non-isokinetic method used to measure the moisture content of
gas streams. Gas is sampled at a constant sampling rate through a probe and impinger
train. Moisture is removed using a series of pre-weighed impingers containing methodology-
specific liquids and silica gel immersed in an ice water bath. The impingers are weighed
after each run to determine the percent moisture.
Pertinent information regarding the performance of the method is presented below:
Method Options:
o Since it is theoretically impossible for measured moisture to be higher
than psychrometric moisture, the psychrometric moisture is also
calculated, and the lower moisture value is used in the calculations
o EPA Approved Alternative Method 009 (ALT-009) is used as an alternative
to a two-point post-test meter box calibration. This procedure uses a
calculation to check the meter box calibration factor rather than requiring
a physical post-test meter box calibration using a standard dry gas meter.
The average calculated meter box percent (%) error must result in a
percent error within ±5% of Y. If not, a full calibration is performed, and
the results are presented using the Y factor that yields the highest
emissions.
Method Exceptions:
o One (1), forty-eight (48) minute moisture determination run will be
conducted for every three (3) gaseous pollutants run for GT #1, GT #2,
and GT #3.
3.1.4 EPA Methods 3A, 7E, 10, and 20 Determination of Oxygen,
Carbon Dioxide, Nitrogen Oxides, and Carbon Monoxide
Concentrations in Emissions from Stationary Sources /Stationary
Gas Turbines (Instrumental Analyzer Procedures)
3A, 7E/20, and 10, which are instrumental test methods. Conditioned gas is sent to a series
of analyzers to measure the gaseous emission concentrations. The performance
requirements of the method must be met to validate the data.
Pertinent information regarding the performance of the method is presented below:
Method Quality Assurance/Quality Control:
o The main quality assurance criteria for EPA Method 10 requires that the
following items are met:
1. EPA Protocol 1 gas standards consisting of CO, balance nitrogen, in
the following concentrations:
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Zero gas (<0.1 ppm CO); MAQS has a zero gas of purified
N2 that is <0.1 ppm CO.
Mid-level calibration gas with a CO concentration between
40 and 60 percent of the span level: MAQS’s mid-level
calibration gas will be 12.6 ppm CO, which is in the
acceptable range.
High-level calibration gas with a CO concentration equal to
the upper span value for the test; MAQS’s high-level
calibration gas will be 25.4 ppm CO, which is in the
acceptable range.
2. EPA Protocol 1 gas standards consisting of O 2, balance nitrogen, in
the following concentrations:
Mid-level calibration gas with a O2 concentration between 40
and 60 percent of the span level: MAQS’s mid-level
calibration gas will be 10.01% O2, which is in the acceptable
range.
High-level calibration gas for O2 equivalent to purified air at
21.08%.
o The main quality assurance criteria for EPA Methods 7E/20 requires that
the following items are met:
3. EPA Protocol 1 gas standards consisting of NOX, balance nitrogen,
in the following concentrations:
Zero gas (<0.1 ppm NOX); MAQS has a zero gas of purified
N2 that is <0.1 ppm NOX.
Mid-level calibration gas with a NOX concentration between
40 and 60 percent of the span level: MAQS’s mid-level
calibration gas will be 12.3 ppm NOX, which is in the
acceptable range.
Span value calibration gas for NOX equivalent to the span
value; MAQS’s high-level calibration gas will be 23.7 ppm
NOX, which is in the acceptable range.
A certified NO2 gas in the appropriate range/span, balance air, is
used to perform the required NOX converter efficiency test; the
alternative NOX converter efficiency test described in EPA Method
7E Section 16.2 may be used (bag procedure)
Method Options:
o A dry extractive sampling system is used to report emissions on a dry
basis (% vd for O2/CO2 and ppmvd for NOX and CO)
o A paramagnetic analyzer is used to measure O2
o A non-dispersive infrared analyzer is used to measure CO 2
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o A chemiluminescent analyzer is used to measure NOX
o A gas filter correlation non-dispersive infrared analyzer is used to measure
CO
o Target Sample Duration: Three (3) 30-minute runs per four (4) load
conditions for GT #1; three (3) 30-minutes runs for normal load condition
for GTs #2 and #3
3.1.5EPA Method 9, Visual Determination of the Opacity of Emissions
EPA Method 9 is used to observe the visual opacity of emissions (opacity). The observer
stands at a distance sufficient to provide a clear view of the emissions with the sun oriented
in the 140° sector to their back. The line of vision is perpendicular to the plume direction
and does not include more than one plume diameter. Observations are recorded at 15-
second intervals and are made to the nearest 5% opacity. The qualified observer is certified
according to the requirements of EPA Method 9, section 3.1.
Pertinent information regarding the performance of the method is presented below:
Method Options:
Observations are attempted to be made during each concurrent NOX and
CO run, unless weather conditions are unfavorable.
Total Observation Period Duration: 6 minutes (40 CFR Part 60, Subpart I)
3.2 Process Test Methods
The applicable regulations do not require process samples to be collected during this test
program.
4.0 Quality Assurance and Reporting
4.1 QA Audits
Montrose has instituted a rigorous QA/QC program for its air quality testing. Quality
assurance audits are performed as part of the test program to ensure that the results are
calculated using the highest quality data available. This program ensures that the emissions
data we report are as accurate as possible. The procedures included in the cited reference
methods are followed during preparation, sampling, calibration, and analysis. Montrose is
responsible for preparation, calibration, and cleaning of the sampling apparatus. Montrose
will also perform the sampling, sample recovery, storage, and shipping. Approved contract
laboratories may perform some of the preparation and sample analyses, as needed.
4.2 Quality Control Procedures
Montrose calibrates and maintains equipment as required by the methods performed and
applicable regulatory guidance. Montrose follows internal procedures to prevent the use of
malfunctioning or inoperable equipment in test programs. All equipment is operated by
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trained personnel. Any incidence of nonconforming work encountered during testing is
reported and addressed through the corrective action system.
4.2.1 Equipment Inspection and Maintenance
Each piece of field equipment that requires calibration is assigned a unique identification
number to allow tracking of its calibration history. All field equipment is visually inspected
prior to testing and includes pre-test calibration checks as required by the test method or
regulatory agency.
4.2.2 Audit Samples
When required by the test method and available, Montrose obtains EPA TNI SSAS audit
samples from an accredited provider for analysis along with the samples. Currently, the
SSAS program has been suspended pending the availability of a second accredited audit
sample provider. If the program is reinstated, the audit samples will be ordered. If required
as part of the test program, the audit samples are stored, shipped, and analyzed along with
the emissions samples collected during the test program. The audit sample results are
reported along with the emissions sample results.
4.3 Data Analysis and Validation
Montrose converts the raw field, laboratory, and process data to reporting units consistent
with the permit or subpart. Calculations are made using proprietary computer spreadsheets
or data acquisition systems. One run of each test method is also verified using a separate
example calculation. The example calculations are checked against the spreadsheet results
and are included in the final report. The “Standard Conditions” for this project are 29.92
inches of mercury and 68 °F.
4.4 Sample Identification and Custody
The on-site Field Project Manager will assume or assign the role of sample and data
custodian until relinquishing custody. The sample custodian will follow proper custody
procedures before departing from the test site including:
Assign the unique sample identification number to each sample
Attach sample labels and integrity seals to all samples
Complete COC form(s), ensuring that the sample identification numbers on
the samples match the sample identification numbers on the COC
Pack and store samples in accordance with the test method requirements in
appropriate transport containers for protection from breakage, contamination,
or loss
Keep samples in a secure locked area if not in the direct presence of Montrose
staff
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The sample custodian will follow proper custody procedures upon arriving at the Montrose
office including:
Remove samples and COC documents from vehicles and check into
designated secure sample holding areas
Store samples requiring additional measures such as refrigeration or dry ice
appropriately
4.5 Quality Statement
Montrose is qualified to conduct this test program and has established a quality
management system that led to accreditation with ASTM Standard D7036-04 (Standard
Practice for Competence of Air Emission Testing Bodies). Montrose participates in annual
functional assessments for conformance with D7036-04 which are conducted by the
American Association for Laboratory Accreditation (A2LA). All testing performed by Montrose
is supervised on site by at least one Qualified Individual (QI) as defined in D7036-04
Section 8.3.2. Data quality objectives for estimating measurement uncertainty within the
documented limits in the test methods are met by using approved test protocols for each
project as defined in D7036-04 Sections 7.2.1 and 12.10. Additional quality assurance
information is included in the appendices. The content of this test plan is modeled after the
EPA Emission Measurement Center Guideline Document (GD-042).
4.6 Reporting
Montrose will prepare a final report to present the test data, calculations/equations,
descriptions, and results. Prior to release by Montrose, each report is reviewed and certified
by the project manager and their supervisor, or a peer. Source test reports will be
submitted to the facility within 25 days of the completion of the field work. The report will
include a series of appendices to present copies of the intermediate calculations and
example calculations, raw field data, laboratory analysis data, process data, and equipment
calibration data.
4.6.1 Example Report Format
The report is divided into various sections describing the different aspects of the source
testing program. Figure 4-1 presents a typical Table of Contents for the final report.
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2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah

Figure 4-1
Typical Report Format
Cover Page
Certification of Report
Table of Contents
Section
1.0 Introduction
2.0 Plant and Sampling Location Descriptions
3.0 Sampling and Analytical Procedures
4.0 Test Discussion and Results
5.0 Internal QA/QC Activities
Appendices
A Field Data and Calculations
B Facility CEMS and Process Data
C Laboratory Analysis Data
D Quality Assurance/Quality Control
E Regulatory Information
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2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah

4.6.2 Example Presentation of Test Results
Table 4-1 presents the typical tabular format that is used to summarize the compliance
emissions results in the final source test report. Separate tables will outline the results for
each target analyte and compare them to their respective emissions limits.
Table 4-1
Example Emissions Results -
Turbine, Bountiful City Light and Power, Bountiful, Utah

Parameter/Units Run 1 Run 2 Run 3 Average
Date XX XX XX XX
Time XX XX XX XX
Process Data
Unit Load, MW XX XX XX XX
Sampling & Flue Gas Parameters
O2, % volume dry XX XX XX XX
CO2, % volume dry XX XX XX XX
flue gas temperature, °F XX XX XX XX
moisture content, % volume XX XX XX XX
volumetric flow rate, dscfm XX XX XX XX
NOX Results
Concentration, ppmvd XX XX XX XX
Concentration, ppmvd@15% O2 XX XX XX XX
Emission rate, lb/hr XX XX XX XX
Emission rate, g/kW-hr XX XX XX XX
CO Results
Concentration, ppmmd XX XX XX XX
Concentration, ppmvd@15% O2 XX XX XX XX
Emission rate, lb/hr XX XX XX XX
Emission rate, g/kW-hr XX XX XX XX
Opacity of Emissions Results
Opacity, % XX XX XX XX

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2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah

Appendix A
Supporting Information

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Appendix A.1
Units and Abbreviations

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Appendix A.2
Accreditation Information/Certifications

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Accredited Air Emission Testing Body
A2LA has accredited
MONTROSE AIR QUALITY SERVICES
In recognition of the successful completion of the joint A2LA and Stack Testing Accreditation Council (STAC)
evaluation process, this laboratory is accredited to perform testing activities in compliance with
ASTM D7036:2004 - Standard Practice for Competence of Air Emission Testing Bodies.
Presented this 27th day of February 2024.
_______________________
Vice President, Accreditation Services
For the Accreditation Council
Certificate Number 3925.01
Valid to February 28, 2026
This accreditation program is not included under the A2LA ILAC Mutual Recognition Arrangement.
American Association for Laborator y Accreditation
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2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah

Appendix A.3
Approval Order DAQE-AN101200006-18

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Appendix “S”
Field Work Safety Plan
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SITE SAFETY PLAN BOOKLET

Project: _____________________
Customer: ___________________
Location: ____________________
Units: _______________________
Client Project Manager: ______________________
Revision Date:January 21, 2022
GP043AS-039663-PP-825 Page 126 of 13943 of 56 GP081AS-041933-PP-861
PROJ-041933SF
Bountiful City L&P
Bountiful, Utah
Turbines GT #1, GT #2, & GT#3
B. Hawkins / C. Guymon
Page 1 of 2
Site Safety Plan and JHA Purpose and Instructions

Purpose
Employee safety is the top priority of Montrose Environmental Group. All employees must be
trained to assess and mitigate hazards. The District Manager and Project Manager are
responsible to ensure all hazards have been properly identified and managed. All employees
have Stop Work Authority in all situations where an employee feels they or their co-worker
cannot perform a job safely or if there is a task for which they have not been adequately trained.
The Site Safety Plan (SSP) has been developed to help assist Montrose test crews with
identifying physical and health hazards and determining how the hazards will be managed.
Additionally, the SSP will help each crew manage the safety of the employees by providing
emergency procedures and information. The booklet contains a several safety forms that may
be required in the field.
Instructions
The SSP consists of the following:

communicated to all employees, signed, and posted.
Supervisor/ CPM will ensure that this Emergency Action Plan Form is completed,
CPM will maintain a roster and be responsible for accounting for all employees. The Job
to work commencing. In the event of an emergency situation/ evacuation, the Job Supervisor/
emergency and evacuation procedures, assembly/ rally points, alert systems, and signals prior
the Emergency Action Plan form and ensure that all employees are familiar with the facility
4. Emergency Action Plan -The Job Supervisor/ Client Project Manager (CPM) will complete
observed plus applicable PPE that may be required.
administrative controls that a crew can use to reduce or eliminate the hazards they have
3. Hazard Control Matrix - contains useful information on both engineering and
with the toolbox topic and signatures can be added to the SSP packet.
the hazard analysis is required daily for the duration of the test. An additional sheet of paper
modified when conditions change. A toolbox meeting with a daily topic in addition to a review of
sign on the Job Hazard Analysis form in agreement and sign in Section 10. The JHA is to be
Each team member has the option to discuss making changes or adding to the JHA and must
Section 9 will require at least three tasks, hazards and controls be identified for the project.
form for accuracy, making any corrections required and complete the remainder of the JHA.
complete the JHA form through section 8. Upon arrival at the test site, the team will review the
daily hazard review with sign off by the team. The client Project Manager is responsible to
and controls. The form also includes a daily toolbox topic and
2. A Job Hazard Analysis is a standardized, two-page, fillable form that is used to evaluated the
prior to the test.
1. A Pre-Mobilization Test Plan
AQS-FRM-1.13R1
Extended Hours Formc.
Heat Stress Prevention Form Based on Heat Indexb.
MEWP Lift Inspection Forma.
Additional Forms, as applicable5.
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Page 2 of 2
Site Safety Plan and JHA Purpose and Instructions

The SSP is a living document. The Project Manager should continually update their SSPs as
new information and conditions change or if new hazards are presented.
Each completed SSP should be maintained with the Test Plan in the office for a period of 3
years. There will be an audit process developed for the Site Safety Plans.

AQS-FRM-1.13R1
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Page 1 of 2
PRE-MOBILIZATION TEST INFORMATION

Source Type: New Source: ____ Revisit: ____ Prj#/Date/Tech: __________________________
Coal Fired Electric Utility: ____ Ethanol Plant: ____ Chemical Mfg. of _________________________
Cement/Lime Kiln Plant: ____ Specialty Mfg. of: ___________ Other: _______________

Anticipated Effluent Composition check all that apply and fill in expected concentration in ppm/%

CO NOX SO2 VOC other
If other, explain: _______________________________________________________

Flammable: _______ Toxic: ________ Corrosive: _______ Dust: __________
Engineering Controls to be Implemented:
______________________________________________________________________________________
__________________________________________________________________________________
Additional Safety Equipment Required:
Personal gas monitors: ____
Respiratory Protection:
Half Face____ Full Face____ HEPA Filters____ Supplied Air: _____ (Safety Dept. Approval)
Approximate Flue Gas Temperatures, (F)

below 210 210 to 450 450 to 950 above 950 other
If other, explain: _______________________________________________________
Approximate Duct Pressure, (iwg):

below -3 -3 to +3 +3 to +7 above +7 other
If other, explain: _______________________________________________________

PROJECT NAME/LOCATION: ______________________ PROJECT #: ____________________
TEST DATE: ______________________ PROJECT MANAGER: ___________________
TEST SCOPE: _________________________________________________________________
SITE CONTACT: Name: _____________________ Contact Phone: _________________________
AQS-FRM-1.17
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Page 2 of 2
PRE-MOBILIZATION TEST INFORMATION

Sampling Location: Stack Port ____ Duct Port ____
Approximate Sampling Platform Height, (ft)

Effluent Chemical Regulatory Limits

Gas Name Chemical
Formula
Cal OSHA PEL1
(ppm)
Cal OSHA
STEL2
(ppm)
NIOSH REL
TWA3 (ppm)
Cal OSHA
Ceiling
(ppm)
IDLH4
(ppm)
Carbon Monoxide CO 25 200 35 200 1,200
Nitric Oxide NOx 25 ND5 25 ND 100
Sulfur Dioxide SO2 2 5 2 ND 100
Hydrogen Chloride HCl 0.3 2 ND 2 50
Hydrogen Sulfide H2S 10 15 10 (10 min.)C 50 100
1: California Occupational Safety and Health Administration (OSHA) Permissible Exposure Limit (PEL) based on an 8 -hour shift;
2: Cal OSHA Short-term Exposure Limit (STEL) based on a 15-minute period;
3: National Institute for Occupational Safety and Health (NIOSH) Recommended Exposure Limit (REL) Time-weighted Average (TWA) based
on an 8-hour shift;
4: Immediately Dangerous to Life or Health (IDLH);
5: Not Defined (ND);
C: Ceiling Limit - Maximum allowable human exposure limit for an airborne or gaseous substance, which is not to be exceeded, even
momentarily.

Prepared by: Date:
Reviewed by: Date:

______________________________________________________________________________
______________________________________________________________________________
Additional Information:
______________________________________________________________________________
______________________________________________________________________________
Describe how equipment will be mobilized to the sampling location:
Other:_____________________________________________________________________________
Guardrails: ____ Toe plate: ____ Engineered Tie Off Points: ____ Heat Shield: ____
Elevators: ____ Ladders: ____ MEWP Lift: ____ Scaffold: ____ Equipment Hoist: ____
Access and Protection:
If other, explain: _______________________________________________________
below 6 6 to 50 50 to 100 above 100 other
AQS-FRM-1.17
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Job Hazard Analysis 1 of 3
1.
Client Rep
Job Preparation
Job Site Walk Through Completed Site Specific Training Complete
Safe Work Permit Received from Client
2. Facility Information/Emergency Preparedness
If non-emergency medical attention is needed, call: AXIOM #: 877-502-9466.
Plant Emergency # Certified First Aid Person:
EMS Location Evacuation Routes Rally Point
Severe Weather Shelter Location Eye Wash & Safety Shower Location
Operational: Yes No
Source Information: (list type):
Stack Gas Temp. (oF)Stack Gas Press. ("H2O)Stack Gas Components:
Stack Gas Inhalation Potential?Yes No If yes, see List of Hazard Chemicals.
3. Error Risk
Time Pressure Remote Work Location > 12 hr shift Working > 8 consecutive days
Lack of procedures Extreme temps, wind >30mph Personal illness/fatigue Vague work guidance
Monotonous Activity First day back after time off Multiple job locations Other:
4. Physical Hazards Hazard Controls
Dust Hazards Dust Mask Goggles Other:
Thermal Burn Hot Gloves Heat Shields Other Protective Clothing:
Electrical Hazards Connections Protected from Elements External GFCI Other:
XP Rating Requirement Intrinsically Safe Requirement
Inadequate Lighting Install Temporary Lighting Headlamps
Slip and Trip Housekeeping Barricade Area Other:
Hand Protection Cut Resistant Gloves Pinch Pts. General Electrical Impact Resistant
Other:
Potential Hazards for Consideration
Secondary Permits Hot Work Confined Space
Excavation
Working from Heights Falling objects Fall protection Drop zone protection Platform load ratings
See also Sect. 7 Scaffold inspection Ladder inspection Barricades for equipment
Electrical Exposed wire/connector Verify equipment grounding Arc Flash
Lifting Crane lift plan Rigging inspection Tag lines used Hoists in place
Respiratory Unexpected exposure Chemical Dust (combustible) PEL provided
See also Sect. 8 Cartridges or supplied air available Gas detection equipment
5. Required PPE Hard Hats Safety Glasses Safety Toe Shoe/Boot Hearing Protection Safety Spotter
Hi-Vis Vests Harness/Lanyard*Goggles Personal Monitor Type:
Metatarsal Guards Hot Gloves Face Shield Respirator Type:
Nomex/FRC Other PPE:
Client Contact Name Date
Facility SSP Writer PM
If the heat index is expected to be above 91°, fill out the Heat Stress Prevention Form.
All hazards and mitigation steps must be documented.
If this JHA does not cover all the hazards identified,
use Section 9 to document that information.
AQS-FRM-1.18
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Job Hazard Analysis 2 of 3
Additional Work Place Hazards
6.Critical Procedures *indicates additional form must be completed or collected from client
Heat Stress Prevention* Confined Space* Roof Work Scaffold
Cold Weather Work Hazardous Energy Control* Other:
7. Working From Heights
Fall Protection Fixed Guardrails/Toe boards Fall Prevention PPE Warning Line System
Falling Objects Protection Barricading Netting House Keeping Tethered Tools Catch Blanket or Tarp
Fall Hazard Communication Adjacent/Overhead Workers Contractor Contact Client Contact
8.Other Considerations
Environmental Hazards - Weather Forecast
Heat/Cold Lightning Rain Snow Ice Tornado Wind Speed
Steps for Mitigation:
Electrical Safety Planning
Plant Hook up: 110V 220/240V 480V Generator Hard wired into panel
Electrical Classified Area: Yes No Trailer Grounded: Yes No Plug Type
Electrical Hook Up Responsibility:
List of Hazardous Chemicals Other Chemicals:
Acetone Nitric Acid Hydrogen Peroxide Compressed Gases
Hexane Sulfuric Acid Isopropyl Alcohol Flammable Gas
Toluene Hydrochloric Acid Liquid Nitrogen Non-Flammable Gas
H2S Carbon Monoxide
Steps for Mitigation:
Wildlife/Fauna in Area
Poison Ivy Poison Oak Insects: Wildlife:
Personnel w/ known allergies to bees stings or other allergens?Yes No
9. Observed Hazards and Mitigation Steps
Task Potential Hazard(s)Steps for Mitigation
1 1
2 2
3 3
1 1
2 2
3 3
1 1
2 2
3 3
1 1
2 2
3 3
Exposure Monitoring
MEWP*
AQS-FRM-1.18
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Job Hazard Analysis 3 of 3
10.JHA REVIEW: Crew Names & Signatures
11.Daily JHA Meeting & Review
Items to review:
Change in conditions
New workers or contractors
Printed Name Signature
2
Discussion TopicDay
Initialing demonstrates that site conditions and hazards have not changed from the original SSP. If changes did occur, make the
necessary updates to this JHA and add notes as applicable in Section 9.
Initials
9
8
7
6
3
Date Printed Name Signature Date
5
4
11
10
AQS-FRM-1.18
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1
2
3
4
5
6 Local Hospital/ Clinic Telephone Number:
7
8
9
10
11
12
13
14
15
16
17
MEG Job Supervisor/ CPM's Telephone Number:
Plant's #1 Contact Person's Name:
Plant's #1 Contact Person's Telephone Number:
MEG Job Safety Supervisor's Telephone Number:
Plant's Emergency Telephone Number:
Emergency Ops Radio Channel:
The Fire Extinguisher is Located:
Eye Wash and Safety Shower Location:
The First Aid Kit is Located:
Page 1 of 2
The Job Supervisor/ Client Project Manager (CPM) will ensure that all employees are familiar with the facility emergency and evacuation
procedures, assembly/ rally points, alert systems, and signals prior to work commencing. In the event of an emergency situation/
evacuation, the Job Supervisor/ CPM will maintain a roster and be responsible for accounting for all employees. The Job Supervisor/
CPM will ensure that this Emergency Action Plan Form is completed, communicated to all employees, and posted.
CALL 911 IMMEDIATELLY
If non-emergency medical attention is needed, call AXIOM Medical number: 877-502-9466.
EMERGENCY ACTION PLAN FORM
MEG Job Supervisor/ CPM's Name:
MEG Job Safety Supervisor (if applicable):
Evacuation Routes:
Severe Weather Shelter Location:
Plant's #2 Contact Person's Name:
Plant's #2 Contact Person's Telephone Number:
Designated Assembly Point Location:
AQS-FRM-1.11
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1
2
4
5
Signature: Date: Printed Name: Signature: Date:
EVACUATE:____________________________________;
OTHER:_______________________________________;
Alarm Tones:
EMERGENCY ACTION PLAN FORM AND EVACUATION ASSEMBLY MAP REVIEW: Crew Names and Signatures
Printed Name:
Draw the evacuation and assembly map here
Page 2 of 2
EMERGENCY EVACUATION AND ASSEMBLY MAP
3
Designated Shelter(s) Description:
Designated Assembly Point(s) Description:
YES or NO
Facility Name:
Facility Alarm (Circle):
FIRE:_________________________________________;
CHEMICAL/ GAS:_______________________________;
SHELTER-IN-PLACE:_____________________________;
AQS-FRM-1.11
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Serial Number:
Make: Rented or Owned:

Check if an item is adequate, operational, and safe.

Yes No N/A

2. Hydraulic fluid level is sufficient, with the platform fully lowered
3. Hydraulic system pressure (see manufacturer specs) is acceptable.
If the pressure is low, determine cause and repair in accordance with accepted procedures
as outlined in service manual.

4. Tires and wheel lug nuts (for tightness)
5. Hoses and cables (i.e. worn areas or chafing)
6. Platform rails and safety gate (no damage present)
7. Pivot pins secure
8. Welds are not cracked and structural members are not bent or broken
9. Warning and instructional labels are legible and secure, and load capacity is clearly marked.
10
11. Base controls (switches and push buttons) can be properly operated
12. Platform conditions are safe (i.e. not slippery)
13. Fire extinguisher is present, mounted and fully charged, located inside the bucket
14. Headlights, safety strobe light and back-up alarm are functional
15. Workplace is free of hazards (overhead powerlines, obstructions, level surface, high winds,
etc.) *Do not operate if winds are 20 mph, unless otherwise specified by manufacturer
recommendations.

Operator Name & Signature Location Date

Ground Control Name & Signature Location Date

Harness Inspections:

Printed Name Signature Date

Printed Name Signature Date

Printed Name Signature Date
Daily MEWP Lift Inspection Form
Page 1 of 1
atthe beginning of each shift or following 6 to 8 hours of use.
All checks must be completed prior to each work shift, before operation of the MEWP lift. This checklist must be used
MEWP Lift Model #:
loose hoses, etc.)if something can be easily loosened by hand then it is not sufficient.
1.All MEWP lift components are in working condition (i.e. no loose or missing parts, torn or
Items to be Inspected
AQS-FRM-1.16
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Page 1 of 1
001AS-SAFETY-FM-3
Extended Hours Safety Audit
Project Number: Date: Time:
When a project is expected to extend past a 14-hour work day, this form must be completed to evaluate
the condition of the crew, and the safety of the work environment.
Permission to proceed into extended work hours must come from a District Manager (DM) or Regional Vice
President (RVP). Technical RVPs can authorize moving forward, if they are in the field or if they are
managing the project.
1.Hold test crew meeting Test crew initials:
The test leader should look for signs of the following in their crews:
Irritability
Lack of motivation
Headaches
Giddiness
Fatigue
Depression
Reduced alertness, lack of concentration and
memory
The test leader should assess the environmental and hazardous concerns:
Temperature and weather
Lighting
Working from Heights
Hoisting
PPE (i.e. respirators, etc.)
Pollutant concentration in ambient air (SO2,
H2S, ect.)
Reason for extended hours
Reason for delay
Production limitations
Impending Weather
3.Contact the client
The PM, DM or RVP must discuss with client any identified safety concerns, the needs and
mutually agree on how to proceed. Discussion should also include the appropriate rest period
needed shift can begin. The DM and/or a RVP must be informed on the
final decision.
Final Outcome:
Approver:
During this time, they can come to an agreement on how to proceed. Itemsto discuss include:
extended work period. If the DM is the acting PM on the job site, they must contact the RVP.
The PM must contact either the DM or RVP to discuss the safety issues that may arise due to the
Notify DM or RVP2.
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Page 1 of 1

001AS-SAFETY-FM-5

Heat Stress Prevention Form

This form is to be used when the Expected Heat Index is above 91° F, and is to be kept with project
documentation.

Project Manager (PM): Expected High Temp:
Date(s): Expected Heat Index:

1. Review the signs of Heat Exhaustion and Heat Stroke

2. If Heat Index is above 91° F:
Provide cold water and/or sports drinks to all field staff (avoid caffeinated drinks and energy
drinks which can increase core temperature).
o Bring no less than one gallon of water per employee
If employee(s) are dehydrated, on blood pressure medication or not acclimated to heat,
ensure they are aware of the heightened risk for heat illness
Provide cool head bands/vests/etc.
Have ice available to employees
Implement work shift rotations and breaks, particularly for employees working in direct
sunlight.
Provide as much shade at the jobsite as possible, including tarps, tents or other acceptable
temporary structures.
PM should interview each field staff periodically to evaluate for signs of heat illness

3. If Heat Index is above 103° F:
Employees must stop for drinks and breaks every hour (about 4 cups/hour)
Employees are not permitted to work alone for more than one hour at a time without a
break offering shade and drinks
Employees should wear cool bands and vests if working outside more than one hour at a
time
PM should interview each field staff every 2 hours to evaluate for signs of heat illness

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Bountiful City Light and Power
2024 NOX, CO, and VEOs Compliance Source Test Plan, Three (3) Turbines, Bountiful, Utah

This is the Last Page of This Document
If you have any questions, please contact one of the following
individuals by email or phone.

Name: Beckie Hawkins
Title: District Manager
Region: Great Plains Region, Utah Office
Email: [e-mail]
Phone: [phone]

Name: Cheyney Guymon
Title: Field Project Manager
Region: Great Plains Region, Utah Office
Email: [e-mail]
Phone: [phone]
56 of 56 GP081AS-041933-PP-861