DAQ-2025-001327

1

DAQC-205-25
Site ID 10790 (B4)

MEMORANDUM

TO: STACK TEST FILE – BRINGHAM YOUNG UNIVERSITY – Main Campus –
Utah County

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

FROM: Kyle Greenberg, Environmental Scientist

DATE: February 21, 2025

SUBJECT: Sources: Boilers 4 and 6
Contact: Brian Harris: [phone]
Location: Brigham Young University, Provo, UT 84602
Test Contractor: TETCO
Permit/AO#: DAQE-AN107900021-23, dated May 24, 2023
Action Code: TR
Subject: Review of stack test report dated February 6, 2025

On February 7, 2025, Utah Division of Air Quality (DAQ) received a test report for the above listed units.
Testing was performed February 5-6, 2025, to demonstrate compliance with the emission limits found in
Condition 11.B.2.b of DAQE-AN107900021-23. The calculated test results are:

Source Test
Date
Test
Methods Pollutants Tester Results DAQ Results Limits
Boiler 4 February
5, 2025 7E NOx 10.7 lb/hr
29.6 ppm@15%O2
10.695 lb/hr
29.537
ppm@15%O2
19.2 lb/hr
36 ppm@15%O2
Boiler 6 February
6, 2025 7E NOx 7.1 lb/hr
32.2 ppm@15%O2
7.093 lb/hr
32.764
ppm@15%O2
19.2 lb/hr
36 ppm@15%O2

DEVIATIONS: None.

CONCLUSION: The stack test report appears to be acceptable.

RECOMMENDATION: The emissions from Boiler #4 and Boiler #6 should be considered to
have been in compliance with the emission limits of the AO during the
time of testing.

HPV: None.

ATTACHMENTS: DAQ stack test review excel spreadsheets, Brigham Young University
stack test report.
4 ' - ) - "
Emissions
Bringham Young University
Main Campus
Utah County
Boiler #4
Test Date: 2/5/25
Run # 1 2 3 Average
Start Time 6:23 7:38 8:56
Stop Time 7:28 8:45 10:01
Sample Duration (minutes) 60 60 60
DS Stack Diameter (inches) 71.6 71.6 71.6 71.6PAVG Average (Delta P)½ (" H2O)½0.4115 0.4591 0.4406 0.4371
CP Pitot Tube Constant (unitless) 0.84 0.84 0.84 0.84
TS Stack Temperature (°F) 335 350 354 346
Pbar Barometric Pressure (" Hg) 25.05 25.05 25.05 25.05
Yd Meter Y Factor (unitless) 0.9970 0.9970 0.9970 0.9970
Tm Meter Temperature (°F) 68 69 69 69
Vm Sample Volume (ft3)40.728 40.768 40.697 40.731
H Orifice Pressure Delta H (" H2O)1.2 1.2 1.2 1.2
Vlc Moisture (g) 89.1 89.2 84.6 87.6
O2%vd O2 (%vd)10.1 9.9 10.1 10.1
CO2%vd CO2 (%vd)6.4 6.6 6.3 6.5
N2%vd N2 (%vd)83.4 83.5 83.5 83.5
dry NOX (ppmvd)54.6 55.2 53.0 54.3
Run # 1 2 3 Average
Vmstd Sample Volume (dscf) 34.069 34.090 34.030 34.063
Vwstd Moisture Volume (scf) 4.20 4.21 3.99 4.13
Bws Measured Moisture Content (%/100) 0.110 0.110 0.105 0.108
Bws Saturated Moisture Content (%/100) 8.947 11.026 11.628 10.534
Bws Actual Moisture Content (%/100) 0.110 0.110 0.105 0.108
MD Molecular Weight Dry (lb/lb-mole) 29.44 29.45 29.42 29.44
MA Molecular Weight Wet (lb/lb-mole) 28.18 28.19 28.22 28.20
VS Gas Velocity (ft/sec) 31.4 35.3 34.0 33.5
FACFM Gas Flow (acfm) 52670 59328 57049 56349
FDSCFM Gas Flow (dscfm) 26067 28792 27699 27519
FWSCFM Gas Flow (wscfm) 29301 32365 30965 30877
FKWSCFH Gas Flow (kwscfh) 1758 1942 1858 1853
FKWSCFM Gas Flow (kwscfm) 29 32 31 31
lb/hr Gas Flow (lb/hr) 128589 142096 136102 135596
Fo Fo (unitless)1.673 1.670 1.694 1.679
wet O2 (%vw)9.0 8.8 9.1 9.0
wet CO2 (%vw)5.7 5.9 5.7 5.8
wet NOX (ppmvw)48.627 49.135 47.450 48.404
15 NOX (ppmvd @ 15% O2)29.899 29.633 29.080 29.537 36.0
lb/hr NOX (lb/hr)10.194 11.378 10.512 10.695 19.2
Permit Limits
Field Reference Method Data
Reference Method Calculations
Page 1 of 5
Linearity
Bringham Young University
Main Campus
Utah County
Boiler #4
Test Date: 2/5/25
O2 CO2 NOX
20.7 20.4 92.9
9.72 9.66 47.1
0.0 0.0 0.1
9.7 9.7 47.2
Linearity Bias (Zero) 0.0 0.0 0.4
Linearity Bias (Span) 9.7 9.8 47.1
% % (ppm)
0.00 0.00 0.0
9.72 9.66 47.1
20.73 20.41 92.9
0.0 0.0 0.4
9.7 9.8 47.1
20.5 20.2 91.8
0.0 0.0 0.4
0.0 0.1 0.0
0.2 0.3 1.1
0.0 0.0 0.0
0.19% 0.05% 0.32%
0.10% 0.44% 0.11%
1.16% 1.27% 1.18%
Gas Concentration
1
2
3
Linearity Information
Gas
Span Gas Value/Range
Bias Gas Value
4
Difference
1
4
Response
1
2
Span Bias
Max Calibration Error
Bias Check (Zero)
Bias Check (Span)
2
3
4
Results
3
Zero Bias
Page 2 of 5
Run 1
Bringham Young University Run 1
Main Campus
Utah County Start Time 6:23
Boiler #4 Run Length 60
Test Date: 2/5/25 Stop Time 7:28
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.0 0.1
9.7 9.7 47.2
0.0 0.1 0.1
9.8 9.7 47.5
0.2% 0.4% 0.3%
0.3% 0.4% 0.4%
0.0% 0.5% 0.0%
0.4% 0.0% 0.3%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
10.1 6.4 54.6
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 10.1 6.5 54.9
Zero%
Span%
Absolute Bias (Zero)
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Results
Post Test Calibration
Calibration Information
Instrument Range
Span Gas Value
Gas
Calibration
Pretest Calibration
Zero%
Span%
Page 3 of 5
Run 2
Bringham Young University Run 2
Main Campus
Utah County Start Time 7:38
Boiler #4 Run Length 60
Test Date: 2/5/25 Stop Time 8:45
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.1 0.1
9.8 9.7 47.5
0.0 0.1 0.9
9.7 9.8 47.7
0.2% 0.2% 0.5%
0.2% 0.1% 0.6%
0.0% 0.2% 0.9%
0.1% 0.3% 0.2%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
9.9 6.6 55.2
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 9.9 6.7 55.7
Gas
Instrument Range
Post Test Calibration
Zero%
Span Gas Value
Calibration
Pretest Calibration
Zero%
Calibration Information
Results
Absolute Bias (Zero)
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Span%
Span%
Page 4 of 5
Run 3
Bringham Young University Run 3
Main Campus
Utah County Start Time 8:56
Boiler #4 Run Length 60
Test Date: 2/5/25 Stop Time 10:01
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.1 0.9
9.7 9.8 47.7
0.1 0.1 1.0
9.8 9.8 47.4
0.3% 0.5% 0.6%
0.5% 0.0% 0.3%
0.1% 0.2% 0.1%
0.3% 0.1% 0.3%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
10.1 6.3 53.0
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 10.2 6.5 53.4
Post Test Calibration
Instrument Range
Zero%
Results
Absolute Bias (Zero)
Span%
Span%
Zero%
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Calibration Information
Span Gas Value
Calibration
Pretest Calibration
Gas
Page 5 of 5
Emissions
Bringham Young University
Main Campus
Utah County
Boiler #6
Test Date: 2/6/25
Run # 1 2 3 Average
Start Time 6:30 7:52 9:09
Stop Time 7:39 8:59 10:15
Sample Duration (minutes) 60 60 60
DS Stack Diameter (inches) 71.6 71.6 71.6 71.6PAVG Average (Delta P)½ (" H2O)½0.2390 0.2679 0.2424 0.2498
CP Pitot Tube Constant (unitless) 0.84 0.84 0.84 0.84
TS Stack Temperature (°F) 335 358 362 352
Pbar Barometric Pressure (" Hg) 25.15 25.15 25.15 25.15
Yd Meter Y Factor (unitless) 0.9900 0.9900 0.9900 0.9900
Tm Meter Temperature (°F) 75 80 80 78
Vm Sample Volume (ft3)44.145 45.231 44.722 44.699
H Orifice Pressure Delta H (" H2O)1.2 1.2 1.2 1.2
Vlc Moisture (g) 103.9 101.6 92.2 99.2
O2%vd O2 (%vd)9.0 9.4 10.1 9.5
CO2%vd CO2 (%vd)7.4 6.6 6.3 6.8
N2%vd N2 (%vd)83.7 84.0 83.6 83.7
dry NOX (ppmvd)66.4 64.8 58.9 63.4
Run # 1 2 3 Average
Vmstd Sample Volume (dscf) 36.394 36.944 36.467 36.601
Vwstd Moisture Volume (scf) 4.90 4.79 4.35 4.68
Bws Measured Moisture Content (%/100) 0.119 0.115 0.107 0.113
Bws Saturated Moisture Content (%/100) 8.948 12.066 12.775 11.263
Bws Actual Moisture Content (%/100) 0.119 0.115 0.107 0.113
MD Molecular Weight Dry (lb/lb-mole) 29.54 29.44 29.41 29.46
MA Molecular Weight Wet (lb/lb-mole) 28.17 28.13 28.20 28.16
VS Gas Velocity (ft/sec) 18.2 20.7 18.7 19.2
FACFM Gas Flow (acfm) 30543 34748 31487 32259
FDSCFM Gas Flow (dscfm) 15020 16686 15178 15628
FWSCFM Gas Flow (wscfm) 17053 18862 16998 17638
FKWSCFH Gas Flow (kwscfh) 1023 1132 1020 1058
FKWSCFM Gas Flow (kwscfm) 17 19 17 18
lb/hr Gas Flow (lb/hr) 74802 82612 74637 77350
Fo Fo (unitless)1.623 1.734 1.715 1.691
wet O2 (%vw)7.9 8.3 9.1 8.4
wet CO2 (%vw)6.5 5.9 5.6 6.0
wet NOX (ppmvw)58.499 57.349 52.648 56.165
15 NOX (ppmvd @ 15% O2)32.774 33.237 32.282 32.764 36.0
lb/hr NOX (lb/hr)7.137 7.739 6.403 7.093 19.2
Permit Limits
Field Reference Method Data
Reference Method Calculations
Page 1 of 5
Linearity
Bringham Young University
Main Campus
Utah County
Boiler #6
Test Date: 2/6/25
O2 CO2 NOX
20.7 20.4 92.9
9.72 9.66 47.1
0.0 0.0 -0.1
9.6 9.5 47.4
Linearity Bias (Zero) -0.1 0.0 0.2
Linearity Bias (Span) 9.8 9.9 47.0
% % (ppm)
0.00 0.00 0.0
9.72 9.66 47.1
20.73 20.41 92.9
-0.1 0.0 0.2
9.8 9.9 47.0
20.8 20.1 93.0
0.1 0.0 0.2
0.0 0.2 0.1
0.1 0.4 0.1
0.0 0.0 0.0
0.14% 0.00% 0.32%
0.58% 1.71% 0.43%
0.24% 1.76% 0.22%
Span Bias
Max Calibration Error
Bias Check (Zero)
Bias Check (Span)
2
3
4
Results
3
Zero Bias
4
Difference
1
4
Response
1
2
Gas Concentration
1
2
3
Linearity Information
Gas
Span Gas Value/Range
Bias Gas Value
Page 2 of 5
Run 1
Bringham Young University Run 1
Main Campus
Utah County Start Time 6:30
Boiler #6 Run Length 60
Test Date: 2/6/25 Stop Time 7:39
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.0 -0.1
9.6 9.5 47.4
0.0 0.0 0.2
9.7 9.5 48.0
0.3% 0.0% 0.0%
0.2% 1.8% 1.1%
0.1% 0.0% 0.3%
0.3% 0.1% 0.6%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
9.0 7.4 66.4
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 8.9 7.2 67.2
Post Test Calibration
Calibration Information
Instrument Range
Span Gas Value
Gas
Calibration
Pretest Calibration
Zero%
Span%
Zero%
Span%
Absolute Bias (Zero)
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Results
Page 3 of 5
Run 2
Bringham Young University Run 2
Main Campus
Utah County Start Time 7:52
Boiler #6 Run Length 60
Test Date: 2/6/25 Stop Time 8:59
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.0 0.2
9.7 9.5 48.0
0.0 0.0 0.2
9.7 9.7 47.2
0.3% 0.2% 0.0%
0.0% 0.7% 0.2%
0.0% 0.1% 0.0%
0.2% 1.1% 0.9%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
9.4 6.6 64.8
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 9.4 6.6 65.4
Calibration Information
Results
Absolute Bias (Zero)
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Span%
Span%
Gas
Instrument Range
Post Test Calibration
Zero%
Span Gas Value
Calibration
Pretest Calibration
Zero%
Page 4 of 5
Run 3
Bringham Young University Run 3
Main Campus
Utah County Start Time 9:09
Boiler #6 Run Length 60
Test Date: 2/6/25 Stop Time 10:15
O2 CO2 NOX
20.7 20.4 93
9.72 9.66 47.1
0.0 0.0 0.2
9.7 9.7 47.2
0.0 0.0 0.2
9.7 9.7 47.2
0.4% 0.1% 0.0%
0.0% 0.9% 0.2%
0.1% 0.0% 0.0%
0.0% 0.2% 0.0%
Corrected O2 % Corrected CO2 % Corrected NOX ppm
10.1 6.3 58.9
Run Length
(Minutes) Uncorrected O2 % Uncorrected CO2 % Uncorrected NOX ppm
60 10.2 6.3 59.0
Absolute Bias (Span)
Absolute Drift (Zero)
Absolute Drift (Span)
Calibration Information
Span Gas Value
Calibration
Pretest Calibration
Gas
Post Test Calibration
Instrument Range
Zero%
Results
Absolute Bias (Zero)
Span%
Span%
Zero%
Page 5 of 5

NOX COMPLIANCE TEST
CONDUCTED AT
BRIGHAM YOUNG UNIVERSITY
CENTRAL HEATING PLANT
BOILER #4 AND BOILER #6

February 4-5, 2025

by:

TETCO
391 East 620 South
American Fork, UT 84003

Prepared for:

Brigham Young University
Physical Plant Department
2137 Brewster Building
Provo, UT 84602

Date of report:
February 6, 2025

iii
TABLE OF CONTENTS

PAGE
Introduction
Test Purpose .......................................................................................................................1
Test Location, Type of Process ..........................................................................................1
Test Dates ...........................................................................................................................1
Pollutant Tested and Methods Applied ................................................................................1
Test Participants .................................................................................................................1
Discussion of Errors or Irregularities .................................................................................2
Quality Assurance ..............................................................................................................2

Summary of Results
Emission Results ................................................................................................................3
Process Data .......................................................................................................................3
Gas Analyzer Performance Criteria ...................................................................................3

Source Operation
Process Control Device Operation .....................................................................................4
Process Representativeness ................................................................................................4

Sampling and Analytical Procedures
Sampling Port Location ......................................................................................................5
Sampling Point Location ....................................................................................................5
Sampling Train Description ...............................................................................................5
Sampling and Analytical Procedures .................................................................................6
Quality Assurance ..............................................................................................................6

Appendices
A: Complete Results and Sample Equations
B: Raw Field Data
C: Laboratory Data
D: Raw Production and Control Equipment Data
E: Calibration Procedures and Results
F: Related Correspondence

iv
LIST OF TABLES
Table PAGE
I Measured NOx and CO Emissions .......................................................................................3
II Sample Point Location .......................................................................................................5
III Complete Results, Boiler 4 ............................................................................. Appendix A
IV Complete Results, Boiler 6 ............................................................................. Appendix A

LIST OF FIGURES
Figure
1 Facility Schematic Representation, Boilers 4 and 6 .............................. Appendix D
2 Schematic Representation of Method 4 Sampling Train ....................... Appendix E
3 Schematic of Gas Analyzer Sampling Train .......................................... Appendix E

1
INTRODUCTION

Test Purpose

This test project was conducted to determine the NOx emissions from Boilers No. 4 and 6 while
fired with natural gas. Measured emissions are expressed in ppm corrected to 15 percent
oxygen and pounds per hour. The results are used to determine compliance with the facility
approval order permit.

Test Location, Type of Process

The tests were conducted at the Brigham Young University Central Heating Plant. The plant
provides heating and cooling for the university

The exhaust ducts from Boilers No 4 and 6 combine into a common duct that exhausts to the
atmosphere. When one of the two boilers is not operating, a “Guillotine Gate” can be used to
isolate the down boiler as was done during the compliance test. A stack schematic
representation is given as Figure 1 in Appendix D.

Test Dates

Testing on Boiler No 6 was completed February 4, 2025 and testing on Boiler No 4 was
completed February 5, 2025.

Pollutants Tested and Methods Applied

These tests were for NOx emissions in accordance with EPA Methods 1-4 and 7E.

Test Participants

Test Facility Jared Parrotti Brian Harris

TETCO Dean Kitchen Mike McNamara
Jeremiah Opthof Alan Kitchen

State Agency None

2
Discussion of Errors or Irregularities

There were no errors or irregularities.

Quality Assurance

Testing procedures and sample recovery techniques were in accordance with those outlined in
the Federal Register and the Quality Assurance Handbook for Air Pollution Measurement
Systems.

3
SUMMARY OF RESULTS

Emission Results

Table I presents the test results. More detailed testing data can be found on Tables III, and IV in
Appendix A.

Table I. Measured NOx Emissions and Limits
Source Measured Emissions Emission Limits
ppm @ 15% O2 lb/hr ppm @ 15% O2 lb/hr
Boiler No 4 29.6 10.7 36 19.2
Boiler No 6 32.2 7.1 36 19.2

Process Data

The process was operated according to standard procedures. Boiler 4 averaged 64.8 mmBtu/hr
and Boiler 6 averaged 45.3 mmBtu/hr during the test project. All pertinent process data was
available for recording by agency personnel. Production data is found in Appendix D.

Gas Analyzer Performance Criteria

The gas analyzers met all bias and calibration checks criteria as specified in the Federal Register.
The results of all checks are shown on the Field Data Sheets in Appendix B. The NOx, CO2 and
O2 analyzer performance specifications are applied according to the specifications listed for EPA
Methods 3A and 7E.

4
SOURCE OPERATION

Process Control Devices Operation

All process control devices were operated normally.

Process Representativeness

The facility was operated normally.

5
SAMPLING AND ANALYTICAL PROCEDURES

Sampling Port Location

There was a common exhaust duct for Boilers No 4 and 6. The inside dimensions of the exhaust
duct were 48 inches by 84 inches. The equivalent diameter was calculated at 61.09 inches as
per EPA Method 1, 12.2 for determining upstream/downstream distances for flow rate
disturbances. The sample ports were located 3.63 diameters (18.5 feet) downstream and 1.18
diameters (6 feet) upstream from any flow disturbance. Sample ports were 6 inches in diameter.
Port location is depicted in Figure 1 found in Appendix D.

Sampling Point Location

Table II shows the distance of each sampling point for Method 4 from the inside wall. Each
point is marked and identified on the probe. These points were determined by measuring the
distance from the inside wall and adding the reference (port) measurement.

Table II. Sample Point Location
Sample Point
Distance (inches)
from Inside Wall
1 6.00
2 18.00
3 30.00
4 42.00

Sampling Train Description

To determine the actual emission rates for this stack, 40 CFR Part 60 Appendix A Methods 1-4
and 7E were followed.

All sampling trains were made of Teflon, stainless steel, glass to prevent interference with the
sampled gas.

The stack analyzer used to conduct Methods 1-4 was constructed to meet the specifications
outlined in the CFR. The temperature sensors were K-type thermocouples. Heater, vacuum
and pitot line connections were designed to be interchangeable with all units used by the tester.
The probe liner was made of 316 stainless steel. A sampling train sketch is found as Figure 2 in
Appendix E.

6

Sample boxes were prepared for testing by following the prescribed procedure outlined in
Method 4.

The NOx analyzer was an Horiba, Model CLA 510SS Chemiluminescence. EPA Protocol 1
gases were used as the span and mid-range for the NOx analyzer during all tests; their
concentrations were 92.9 and 47.1 ppm. Dry nitrogen was used as the zero gas for the machine.

The CO2 analyzer was a CAI, Model ZRE analyzer. This analyzer was spanned at 0-20.41
percent. EPA Protocol 1 gases were used as the span and mid-range for the CO2 analyzer
during all tests; their concentrations were 20.41 percent and 9.66 percent respectively. Nitrogen
was used as the zero gas for the analyzer.

The O2 analyzer was a CAI, Model ZRE analyzer. This analyzer was spanned at 0-20.73
percent. EPA Protocol 1 gases were used as the span and mid-range for the CO2 analyzer
during all tests; their concentrations were 20.73 percent and 9.72 percent respectively. Nitrogen
was used as the zero gas for the analyzer.

The gas sampling train was constructed with a stainless steel sampling probe about 60 inches
long. The sample line between the sampling probe and gas conditioner was heated Teflon. The
sample conditioner uses Peltier plates to remove moisture. Sample lines and bias lines from the
gas conditioner to the analyzer were Teflon. A sketch of the sampling train for this method
appears as Figure 3 in Appendix E.

Sampling and Analytical Procedures

All test procedures employed were as specified in 40 CFR 60.

Quality Assurance

All equipment set-up, sampling procedures, sample recovery and equipment calibrations were
carried out according to the procedures specified in 40 CFR 60 and the Quality Assurance
Handbook for Air Pollution Measurement Systems.

7
APPENDICES

A: Complete Results and Sample Equations
B: Raw Field Data
C: Laboratory Data
D: Raw Production and Control Equipment Data
E: Calibration Procedures and Results
F: Related Correspondence

A
APPENDIX A

Table III Complete Results, Boiler No 4
Table IV Complete Results, Boiler No 6
Nomenclature
Sample Equations

TABLE III
COMPLETE RESULTS
BRIGHAM YOUNG UNIVERSITY, PROVO, UTAH
BOILER 4
Symbol Description Dimensions Run #1 Run #2 Run #3
Date 2/5/2025 2/5/2025 2/5/2025
Begin Time Test Began 6:23 7:38 8:56
End Time Test Ended 7:28 8:45 10:01
Pbm Meter Barometric Pressure In. Hg. Abs 25.05 25.05 25.05
H Orifice Pressure Drop In. H2O 1.200 1.200 1.200
Y Meter Calibration Y Factor dimensionless 0.997 0.997 0.997
Vm Volume Gas Sampled--Meter Conditions cf 40.728 40.768 40.697
Tm Avg Meter Temperature oF 68.4 68.6 68.6
P Sq Root Velocity Head Root In. H2O 0.4115 0.4591 0.4406
Wtwc Weight Water Collected Grams 89.1 89.2 84.6
Cp Pitot Tube Coefficient Dimensionless 0.84 0.84 0.84
CO2 Volume % Carbon Dioxide Percent 6.48 6.59 6.35
O2 Volume % Oxygen Percent 10.12 9.91 10.14
N2 & CO Volume % Nitrogen and Carbon Monoxide Percent 83.40 83.50 83.51
Vmstd Volume Gas Sampled (Standard) dscf 34.089 34.111 34.050
Vw Volume Water Vapor scf 4.202 4.207 3.990 AVG
Bws Fraction H2O in Stack Gas Fraction 0.110 0.110 0.105
Xd Fraction of Dry Gas Fraction 0.890 0.890 0.895
Md Molecular Wt. Dry Gas lb/lbmol 29.44 29.45 29.42
Ms Molecular Wt. Stack Gas lb/lbmol 28.19 28.19 28.22
Ts Avg Stack Temperature oF 334.6 350.3 354.4
As Stack Cross Sectional Area Sq. Ft.28.000 28.000 28.000
PG Stack Static Pressure In. H2O -0.24 -0.24 -0.24
Pbp Sample Port Barometric Pressure In. Hg. Abs 25.02 25.02 25.02
Ps Stack Pressure In. Hg. Abs 25.002 25.002 25.002
Qs Stack Gas Volumetric Flow Rate (Std) dscfm 2.60E+04 2.88E+04 2.77E+04 2.74E+04
Qa Stack Gas Volumetric Flow Rate (Actual) cfm 5.27E+04 5.94E+04 5.71E+04 5.60E+04
Vs Velocity of Stack Gas fpm 1.88E+03 2.12E+03 2.04E+03 2.00E+03
CNOx Concentration of NOx ppmdv 54.9 55.3 53.0 54.4
CNOx Concentration of NOx @ 15% O2 ppmdv 30.1 29.7 29.0 29.6
ERn Emission Rate of NOx lb / hr 10.25 11.39 10.50 10.71
TABLE IV
COMPLETE RESULTS
BRIGHAM YOUNG UNIVERSITY, PROVO, UTAH
BOILER 6
Symbol Description Dimensions Run #1 Run #2 Run #3
Date 2/4/2025 2/4/2025 2/4/2025
Begin Time Test Began 6:30 7:52 9:09
End Time Test Ended 7:39 8:59 10:15
Pbm Meter Barometric Pressure In. Hg. Abs 25.15 25.15 25.15
H Orifice Pressure Drop In. H2O 1.200 1.200 1.200
Y Meter Calibration Y Factor dimensionless 0.990 0.990 0.990
Vm Volume Gas Sampled--Meter Conditions cf 44.145 45.231 44.722
Tm Avg Meter Temperature oF 74.5 79.5 80.4
P Sq Root Velocity Head Root In. H2O 0.2390 0.2679 0.2424
Wtwc Weight Water Collected Grams 103.9 101.6 92.2
Cp Pitot Tube Coefficient Dimensionless 0.84 0.84 0.84
CO2 Volume % Carbon Dioxide Percent 7.36 6.64 6.28
O2 Volume % Oxygen Percent 8.44 9.40 10.13
N2 & CO Volume % Nitrogen and Carbon Monoxide Percent 84.19 83.96 83.60
Vmstd Volume Gas Sampled (Standard) dscf 36.415 36.964 36.488
Vw Volume Water Vapor scf 4.900 4.791 4.348 AVG
Bws Fraction H2O in Stack Gas Fraction 0.119 0.115 0.106
Xd Fraction of Dry Gas Fraction 0.881 0.885 0.894
Md Molecular Wt. Dry Gas lb/lbmol 29.52 29.44 29.41
Ms Molecular Wt. Stack Gas lb/lbmol 28.15 28.13 28.19
Ts Avg Stack Temperature oF 334.9 357.6 362.1
As Stack Cross Sectional Area Sq. Ft.28.000 28.000 28.000
PG Stack Static Pressure In. H2O -0.24 -0.24 -0.24
Pbp Sample Port Barometric Pressure In. Hg. Abs 25.12 25.12 25.12
Ps Stack Pressure In. Hg. Abs 25.102 25.102 25.102
Qs Stack Gas Volumetric Flow Rate (Std) dscfm 1.50E+04 1.67E+04 1.52E+04 1.58E+04
Qa Stack Gas Volumetric Flow Rate (Actual) cfm 3.06E+04 3.48E+04 3.15E+04 3.27E+04
Vs Velocity of Stack Gas fpm 1.09E+03 1.24E+03 1.13E+03 1.17E+03
CNOx Concentration of NOx ppmdv 66.3 64.7 58.4 63.1
CNOx Concentration of NOx @ 15% O2 ppmdv 31.4 33.2 32.0 32.2
ERn Emission Rate of NOx lb / hr 7.13 7.73 6.35 7.07
As =stack cross-sectional area (ft3)
AS∆P =see √∆P
Btu =unit heat value (British thermal unit)
Bws =fraction of water in stack gas
CO2 =percent carbon dioxide in the stack gas
Cp =pitot tube coefficient (0.84)
Cgas =concentration (ppm dry basis) of sampled gas using Method 6C, 7E, or 10
corrected for bias checks. Species symbol replaces gas.
Cgas (corr)=actual gas concentration corrected to desired percent O2
Cgas (lb/dscf)=gas concentration converted to lb/dscf
Deq =equivlent diameter for rectangular stack
∆H =orifice pressure drop (inches H2O)
∆H@ =orifice pressure (inches H2O)
∆P =stack flow pressure differential (inches H2O)
Ds =diameter of the stack (feet)
EA =percent excess air
Ergas =emission rate of a gas (lb/hr)
ERmmBtu =emission rate per mmBtu or ton of fuel etc.
ERX =emission rate of compound which replaces x
mBtu =thousand Btu
Md =molecular weight of stack gas, dry basis (lb/lb-mol)
mmBtu =million Btu
Ms =molecular weight of stack gas, wet basis (g/gmol)
Mwgas =molecular weight of gas species (lb/lb-mol)
N2 =percent nitrogen in the stack gas
O2 =percent oxygen in the stack gas
√∆P =average of the square roots of ∆P (may also be referred to as AS∆P)
Pbm =absolute barometric pressure at the dry gas meter (inches Hg)
Pbp =absolute barometric pressure at the sample location (inches Hg)
PG =stack static pressure (inches H2O)
Ps =absolute stack pressure (inches Hg)
Pstd =absolute pressure at standard conditions (29.92 inches Hg.)
θ =time of test (minutes)
Qa =stack gas volumetric flow rate (acfm)
Qs =stack gas volumetric flow rate (dscfm)
Qw =wet stack gas std. volumetric flow (ft3/min, wscfm)
R =gas constant (21.85 inches Hg*ft3/(lbmol*R))
Tm =meter temperature (oF)
Ts =stack temperature (oF)
Tstd =absolute temperature at standard conditions (528oR)
Tt =see θ
Vm =sample volume (ft3) at meter conditions
Method 4 and Gases Nomenclature
Method 4 and Gases Nomenclature
Vmstd =volume standard (dscf), sample volume adjusted to 68oF and 29.92 inches Hg.
Vs =velocity of stack gas (fpm)
Vw =volume water vapor (scf) at 68oF and 29.92 inches Hg.
Wtwc =weight of the condensed water collected (grams)
Xd =fraction of dry gas
Y =meter calibration Y-factor (dimensionless)
As =(Ds2 / 4) • π
Bws =Vw / (Vmstd +Vw)
Cgas (corr)=CX (avg) • (20.9 - desired %O2) / (20.9 - actual %O2)
Deq =2 • L • W / (L + W)
EA =(%O2 - 0.5 %CO) / [0.264 %N2 - (%O2 - 0.5 %CO)]
Ergas =Pstd • Qs • Mwgas • Cgas • 60 / (R • Tstd • 106)
Ergas =Cgas(lb/dscf) • Qs • 60
(Either ERgas equation gives equivalent lb/hr values to 3 sig. figures)
ER(mmBtu)=Cgas(lb/dscf) • Fd • (20.9/(20.9 - %O2), Method 19 Equation 19-1
Md =CO2 • 0.44 + O2 • 0.32 + N2 •0.28
Ms =(Md • Xd) + (18 • Bws)
Ps =Pbp + (PG / 13.6)
Qa =Vs • As
Qs =Qa • Xd • Ps • Tstd / [(Ts + 460) • Pstd]
Qw =Qs / Xd
Vmstd =Vm • Y • Tstd • (Pbm + ∆H / 13.6) / [Pstd • (Tm + 460)]
Vs =85.49 • 60 • Cp • √∆P • √ [(Ts + 460) / (Ps • Ms)]
Vw =Wtwc • 0.04715
Xd =1 - Bws
Method 4 and Gases Sample Equations

B
APPENDIX B

Preliminary Travers and Sampling Point Location Data

Boiler 4
Method 4 Field Data
Gas Analyzer Field Sheets and Data Logger Printout

Boiler 6
Method 4 Field Data
Gas Analyzer Field Sheets and Data Logger Printout

Stratification Check (only one stratification check was completed because the boilers exhaust
through a common duct)

Prelim 20 pts
Facility BYU Central Heating Plant
Stack Identification Boilers 4 & 6
Date 2/4-5/2025
Barometric Pressure
Pbm 25.15 in Hg Pbp 25.12 in Hg
Static Pressure (PG)-0.24 in H2O
Estimated Moisture (Bws)12 %
Sample Height from Ground 30 feet
Comments:
Stack Dia.48 Reference:8
Ports are 6'Upstream from next disturbance
Ports are 18.5'Downstream from last disturbance
Traverse Percent Distance From: Ports
Point Diameter ID Reference A B C D E F
1 12.5 6.00
2 37.5 18.00
3 62.5 30.00
4 87.5 42.00
1 16.7 8.02
2 50.0 24.00
3 83.3 39.98
Averages:
TS  Flow
P P
KEY =>TS  Flow
P
Gas Analyzer Probe
47.98
14.00
26.00
38.00
50.00
16.02
32.00
N
A
C
D
E
B
Boiler 4
Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %
6:23 48.0 6.02 10.83 7:38 56.5 6.68 9.91 8:56 25.1 3.76 4.84
6:24 47.0 5.85 11.11 7:39 55.9 6.57 9.84 8:57 53.3 6.40 10.30
6:25 46.7 5.78 11.24 7:40 56.0 6.56 9.72 8:58 52.9 6.39 10.36
6:26 47.6 5.80 11.22 7:41 55.9 6.61 9.78 8:59 52.7 6.37 10.42
6:27 47.6 5.73 11.34 7:42 56.1 6.64 9.79 9:00 52.8 6.39 10.42
6:28 49.0 5.82 11.24 7:43 55.8 6.64 9.84 9:01 52.5 6.38 10.42
6:29 51.2 6.00 10.90 7:44 55.6 6.62 9.90 9:02 52.3 6.36 10.48
6:30 47.4 5.78 11.24 7:45 55.3 6.59 9.97 9:03 52.6 6.38 10.46
6:31 48.6 5.90 11.08 7:46 55.0 6.59 9.99 9:04 53.1 6.43 10.39
6:32 48.6 5.83 11.17 7:47 55.5 6.62 9.94 9:05 53.2 6.43 10.37
6:33 51.9 6.06 10.86 7:48 55.4 6.63 9.93 9:06 53.5 6.46 10.34
6:34 55.0 6.35 10.35 7:49 55.4 6.63 9.95 9:07 54.0 6.51 10.25
6:35 56.1 6.46 10.15 7:50 55.5 6.63 9.94 9:08 53.5 6.48 10.29
6:36 56.6 6.57 10.00 7:51 55.5 6.64 9.94 9:09 53.4 6.45 10.35
6:37 57.6 6.67 9.81 7:52 55.6 6.66 9.92 9:10 53.0 6.45 10.35
6:38 57.6 6.64 9.87 7:53 56.4 6.74 9.79 9:11 52.4 6.38 10.46
6:39 57.4 6.63 9.90 7:54 56.1 6.74 9.78 9:12 52.4 6.36 10.51
6:40 57.5 6.64 9.89 7:55 55.8 6.70 9.84 9:13 53.0 6.41 10.44
6:41 57.5 6.64 9.89 7:56 56.1 6.73 9.81 9:14 53.4 6.42 10.40
6:42 56.5 6.56 10.00 7:57 55.9 6.72 9.82 9:15 53.9 6.47 10.33
6:43 55.4 6.46 10.19 7:58 55.8 6.69 9.88 9:16 54.3 6.54 10.22
6:44 55.0 6.44 10.24 7:59 56.0 6.72 9.84 9:17 54.4 6.54 10.21
6:45 54.7 6.40 10.30 8:00 56.2 6.74 9.80 9:18 54.4 6.55 10.20
6:46 54.0 6.37 10.36 8:01 56.2 6.72 9.83 9:19 54.3 6.55 10.20
6:47 54.0 6.39 10.34 8:02 56.2 6.74 9.81 9:20 54.5 6.57 10.18
6:48 55.0 6.48 10.19 8:03 56.6 6.75 9.77 9:21 55.0 6.61 10.10
6:49 55.4 6.52 10.12 8:04 56.7 6.76 9.77 9:22 54.7 6.58 10.15
6:50 55.2 6.54 10.08 8:05 56.7 6.77 9.75 9:23 54.5 6.58 10.17
6:51 56.3 6.61 9.95 8:06 56.6 6.76 9.77 9:24 54.5 6.57 10.16
6:52 56.7 6.63 9.91 8:07 56.7 6.76 9.77 9:25 54.0 6.53 10.24
6:53 56.3 6.61 9.96 8:08 56.8 6.75 9.80 9:26 54.2 6.54 10.24
6:54 56.5 6.63 9.93 8:09 56.9 6.75 9.80 9:27 54.6 6.58 10.16
6:55 56.7 6.66 9.89 8:10 56.7 6.75 9.80 9:28 54.5 6.58 10.16
6:56 56.8 6.68 9.86 8:11 56.6 6.75 9.80 9:29 54.4 6.58 10.16
6:57 57.3 6.73 9.77 8:12 56.7 6.74 9.81 9:30 54.1 6.54 10.22
6:58 57.5 6.76 9.71 8:13 56.7 6.75 9.80 9:31 53.3 6.47 10.34
6:59 57.4 6.75 9.73 8:14 56.7 6.75 9.80 9:32 53.6 6.51 10.28
7:00 57.3 6.74 9.76 8:15 56.6 6.75 9.80 9:33 53.7 6.49 10.30
7:01 57.1 6.75 9.73 8:16 56.6 6.75 9.81 9:34 53.7 6.50 10.30
7:02 57.1 6.74 9.75 8:17 56.7 6.75 9.81 9:35 53.8 6.50 10.28
7:03 56.9 6.71 9.81 8:18 56.6 6.74 9.82 9:36 53.1 6.44 10.38
7:04 57.1 6.69 9.82 8:19 56.5 6.74 9.82 9:37 52.9 6.41 10.44
7:05 56.7 6.69 9.84 8:20 56.6 6.75 9.82 9:38 52.7 6.41 10.44
7:06 56.3 6.65 9.91 8:21 56.7 6.74 9.83 9:39 52.0 6.39 10.45
7:07 56.3 6.63 9.94 8:22 56.6 6.73 9.85 9:40 53.3 6.41 10.41
7:08 56.1 6.61 9.98 8:23 56.4 6.73 9.86 9:41 53.7 6.43 10.36
7:09 56.2 6.61 9.98 8:24 55.7 6.66 9.95 9:42 53.6 6.43 10.36
7:10 55.9 6.62 9.96 8:25 55.0 6.58 10.10 9:43 53.9 6.45 10.32
7:11 55.9 6.64 9.92 8:26 54.8 6.56 10.14 9:44 54.0 6.50 10.25
7:12 56.2 6.68 9.87 8:27 54.6 6.54 10.18 9:45 54.0 6.49 10.25
7:13 56.4 6.72 9.78 8:28 54.1 6.51 10.24 9:46 54.1 6.51 10.23
7:14 57.0 6.73 9.76 8:29 54.4 6.52 10.22 9:47 54.6 6.55 10.16
7:15 57.2 6.77 9.70 8:30 54.6 6.55 10.16 9:48 54.7 6.56 10.15
7:16 57.2 6.78 9.67 8:31 54.9 6.57 10.13 9:49 55.0 6.60 10.07
7:17 57.0 6.75 9.72 8:32 55.1 6.58 10.11 9:50 54.8 6.60 10.07
7:18 57.0 6.74 9.74 8:33 55.4 6.63 10.03 9:51 54.9 6.58 10.11
7:19 56.7 6.70 9.80 8:34 55.3 6.64 10.01 9:52 54.8 6.56 10.14
7:20 56.8 6.68 9.83 8:35 55.1 6.61 10.05 9:53 54.0 6.51 10.23
7:21 56.9 6.68 9.85 8:36 55.0 6.59 10.09 9:54 54.1 6.51 10.24
7:22 56.8 6.68 9.85 8:37 54.5 6.54 10.16 9:55 54.2 6.52 10.21
7:23 56.7 6.66 9.88 8:38 53.8 6.48 10.28 9:56 54.1 6.50 10.25
7:24 56.9 6.65 9.90 8:39 53.8 6.49 10.27 9:57 54.5 6.52 10.22
7:25 56.7 6.65 9.90 8:40 54.2 6.49 10.27 9:58 54.6 6.55 10.18
7:26 56.6 6.64 9.91 8:41 54.1 6.50 10.25 9:59 54.4 6.54 10.18
7:27 56.2 6.63 9.94 8:42 54.3 6.51 10.23 10:00 54.6 6.55 10.17
7:28 56.3 6.62 9.95 8:43 54.4 6.54 10.19 10:01 54.5 6.55 10.15
8:44 54.7 6.56 10.16
8:45 55.2 6.60 10.08
Brigham Young University, Boiler 4, February 5, 2023
Run 1 Run 2 Run 3
Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %
Brigham Young University, Boiler 4, February 5, 2023
Run 1 Run 2 Run 3
Raw Avg 55.1 6.50 10.12 Raw Avg 55.76.659.94 Raw Avg 53.4 6.45 10.20
Span 92.9 20.41 20.73 Span 92.9 20.41 20.73 Span 92.9 20.41 20.73
Gas Val 47.19.669.72 Gas Val 47.19.669.72 Gas Val 47.19.669.72
Zeroi 0.1 -0.01 0.02 Zeroi 0.8 0.04 0.02 Zeroi 0.9 0.05 0.03
Zerof 0.8 0.04 0.02 Zerof 0.9 0.05 0.03 Zerof 1.0 0.10 0.05
Spani 47.29.699.68 Spani 47.59.709.76 Spani 47.79.769.74
Spanf 47.59.709.76 Spanf 47.79.769.74 Spanf 47.49.799.81
Corr.54.9 6.48 10.12 Corr.55.36.599.91 Corr.53.0 6.35 10.14
Calibration Calibration Calibration
Span 92.9 20.41 20.73 Span 92.9 20.41 20.73 Span 92.9 20.41 20.73
Zero Cal Gas 0.0 0.00 0.00 Zero Cal Gas 0.0 0.00 0.00 Zero Cal Gas 0.0 0.00 0.00
Mid Cal Gas 47.1 9.66 9.72 Mid Cal Gas 47.1 9.66 9.72 Mid Cal Gas 47.1 9.66 9.72
High Cal Gas 92.9 20.41 20.73 High Cal Gas 92.9 20.41 20.73 High Cal Gas 92.9 20.41 20.73
Zero Resp 0.4 0.00 -0.02 Zero Resp 0.4 0.00 -0.02 Zero Resp 0.4 0.00 -0.02
Mid Cal Resp 47.1 9.78 9.70 Mid Cal Resp 47.1 9.78 9.70 Mid Cal Resp 47.1 9.78 9.70
High Cal Resp 91.8 20.15 20.49 High Cal Resp 91.8 20.15 20.49 High Cal Resp 91.8 20.15 20.49 Limits
Ana. Cal. Error (ACE) ACE ACE
Zero Cal Error 0.43% 0.00% 0.10% Zero Cal Error 0.43% 0.00% 0.10% Zero Cal Error 0.43% 0.00% 0.10% 2.0%
Mid Cal Error 0.00% 0.59% 0.10% Mid Cal Error 0.00% 0.59% 0.10% Mid Cal Error 0.00% 0.59% 0.10% 2.0%
High Cal Error 1.18% 1.27% 1.16% High Cal Error 1.18% 1.27% 1.16% High Cal Error 1.18% 1.27% 1.16% 2.0%
System Bias (zero, SB) SB SB
Sys Zero Cal Bias Initial 0.32% 0.05% 0.19% Sys Zero Cal Bias Initial 0.43% 0.20% 0.19% Sys Zero Cal Bias Initial 0.54% 0.24% 0.24% 5.0%
Sys Zero Cal Bias Final 0.43% 0.20% 0.19% Sys Zero Cal Bias Final 0.54% 0.24% 0.24% Sys Zero Cal Bias Final 0.65% 0.49% 0.34% 5.0%
System Zero Drift (D) 0.75% 0.24% 0.00% System Zero Drift 0.11% 0.05% 0.05% System Zero Drift 0.11% 0.24% 0.10% 3.0%
System Bias (upscale, SB) SB SB
System Cal Bias Initial 0.11% 0.44% 0.10% System Cal Bias Initial 0.43% 0.39% 0.29% System Cal Bias Initial 0.65% 0.10% 0.19% 5.0%
System Cal Bias Final 0.43% 0.39% 0.29% System Cal Bias Final 0.65% 0.10% 0.19% System Cal Bias Final 0.32% 0.05% 0.53% 5.0%
System Cal Drift (D) 0.32% 0.05% 0.39% System Cal Drift 0.22% 0.29% 0.10% System Cal Drift 0.32% 0.15% 0.34% 3.0%
CGas = (Cavg - C0) • [Cma / (Cm - C0)]Eq. 7E-5 Eq. 7E-5
C0 = (C0i + C0f) / 2
Cm = (Cmi + Cmf) / 2
ACE = (CDir - Cv) • 100% / CS Eq. 7E-1 Eq. 7E-1
SB =(Cs - CDir) • 100% / CS Eq. 7E-2 Eq. 7E-2
Drift (D) =ABS(SBfinal - Sbinitial)Eq. 7E-4 Eq. 7E-4
Boiler 6
Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %
6:30 60.0 7.16 7.01 7:52 69.7 6.82 8.71 9:09 58.5 4.99 6.83
6:31 59.5 6.63 9.50 7:53 69.6 6.88 8.73 9:10 60.9 6.36 9.91
6:32 59.3 6.62 9.51 7:54 70.1 6.95 8.68 9:11 60.9 6.41 9.93
6:33 59.5 6.64 9.49 7:55 70.4 7.00 8.61 9:12 60.8 6.43 9.94
6:34 59.9 6.68 9.43 7:56 70.8 7.05 8.54 9:13 61.0 6.46 9.93
6:35 61.0 6.81 9.20 7:57 71.0 7.09 8.49 9:14 61.2 6.48 9.91
6:36 62.4 6.97 8.91 7:58 71.5 7.14 8.42 9:15 61.3 6.49 9.90
6:37 63.2 7.05 8.77 7:59 71.9 7.17 8.36 9:16 61.4 6.50 9.90
6:38 63.2 7.03 8.79 8:00 71.7 7.18 8.34 9:17 61.2 6.51 9.91
6:39 63.1 7.03 8.80 8:01 71.9 7.19 8.32 9:18 61.1 6.51 9.91
6:40 63.1 7.05 8.80 8:02 71.9 7.19 8.33 9:19 61.2 6.49 9.92
6:41 63.1 7.03 8.80 8:03 71.3 7.16 8.39 9:20 61.0 6.49 9.93
6:42 63.1 7.03 8.80 8:04 71.1 7.14 8.44 9:21 60.9 6.48 9.95
6:43 63.9 7.16 8.60 8:05 71.2 7.13 8.45 9:22 60.8 6.47 9.96
6:44 65.1 7.27 8.36 8:06 71.0 7.13 8.45 9:23 60.3 6.44 10.01
6:45 65.5 7.30 8.29 8:07 71.0 7.10 8.49 9:24 60.1 6.42 10.05
6:46 66.1 7.32 8.25 8:08 70.8 7.11 8.49 9:25 59.8 6.39 10.10
6:47 66.1 7.35 8.22 8:09 71.2 7.13 8.46 9:26 59.6 6.36 10.16
6:48 66.3 7.39 8.15 8:10 71.0 7.13 8.45 9:27 59.4 6.35 10.17
6:49 66.5 7.40 8.11 8:11 71.0 7.11 8.48 9:28 59.4 6.36 10.17
6:50 66.7 7.38 8.18 8:12 70.6 7.08 8.53 9:29 59.5 6.36 10.17
6:51 67.8 7.47 8.03 8:13 70.0 7.01 8.65 9:30 59.6 6.36 10.17
6:52 68.3 7.48 7.99 8:14 68.8 6.93 8.82 9:31 59.6 6.37 10.17
6:53 68.4 7.45 8.05 8:15 68.1 6.85 8.95 9:32 59.5 6.36 10.16
6:54 68.3 7.41 8.10 8:16 66.9 6.74 9.13 9:33 59.5 6.36 10.15
6:55 68.4 7.41 8.11 8:17 65.6 6.61 9.39 9:34 59.6 6.36 10.15
6:56 68.3 7.39 8.15 8:18 64.8 6.52 9.54 9:35 59.4 6.37 10.15
6:57 68.5 7.39 8.16 8:19 64.4 6.49 9.60 9:36 59.5 6.37 10.15
6:58 68.4 7.38 8.18 8:20 64.1 6.47 9.63 9:37 59.3 6.34 10.19
6:59 68.7 7.41 8.12 8:21 63.8 6.44 9.70 9:38 58.8 6.31 10.23
7:00 68.9 7.42 8.09 8:22 63.7 6.44 9.70 9:39 58.8 6.33 10.22
7:01 68.8 7.40 8.14 8:23 63.9 6.45 9.69 9:40 58.8 6.30 10.25
7:02 68.6 7.38 8.17 8:24 63.8 6.45 9.68 9:41 58.6 6.29 10.27
7:03 68.6 7.37 8.20 8:25 63.8 6.45 9.68 9:42 58.6 6.29 10.28
7:04 68.6 7.37 8.19 8:26 63.4 6.42 9.73 9:43 58.4 6.28 10.28
7:05 68.8 7.37 8.19 8:27 62.8 6.36 9.82 9:44 58.1 6.26 10.32
7:06 68.7 7.37 8.18 8:28 62.2 6.30 9.95 9:45 58.3 6.26 10.31
7:07 68.8 7.37 8.19 8:29 61.8 6.27 9.99 9:46 58.3 6.27 10.31
7:08 68.6 7.34 8.23 8:30 61.5 6.25 10.02 9:47 58.3 6.27 10.30
7:09 68.3 7.30 8.30 8:31 61.0 6.22 10.09 9:48 58.4 6.29 10.28
7:10 68.0 7.26 8.38 8:32 60.9 6.20 10.13 9:49 58.4 6.29 10.27
7:11 67.7 7.23 8.44 8:33 60.9 6.21 10.12 9:50 58.7 6.31 10.24
7:12 67.6 7.20 8.49 8:34 60.9 6.20 10.12 9:51 58.6 6.30 10.24
7:13 67.4 7.19 8.52 8:35 60.8 6.18 10.16 9:52 58.8 6.31 10.25
7:14 67.3 7.17 8.55 8:36 60.7 6.18 10.16 9:53 58.5 6.29 10.27
7:15 67.2 7.16 8.56 8:37 60.7 6.19 10.15 9:54 58.3 6.26 10.31
7:16 67.3 7.17 8.56 8:38 61.0 6.21 10.12 9:55 58.1 6.25 10.34
7:17 67.7 7.24 8.46 8:39 60.9 6.21 10.12 9:56 57.8 6.22 10.39
7:18 68.4 7.32 8.29 8:40 60.8 6.21 10.13 9:57 57.7 6.21 10.41
7:19 69.1 7.37 8.18 8:41 60.9 6.21 10.13 9:58 57.6 6.21 10.40
7:20 69.9 7.46 8.04 8:42 60.9 6.22 10.12 9:59 57.5 6.21 10.40
7:21 70.5 7.50 7.95 8:43 61.2 6.25 10.07 10:00 57.4 6.22 10.39
7:22 70.3 7.46 8.02 8:44 61.9 6.30 9.97 10:01 57.6 6.23 10.36
7:23 70.1 7.42 8.09 8:45 61.9 6.33 9.94 10:02 57.6 6.24 10.36
7:24 70.5 7.43 8.07 8:46 62.4 6.38 9.87 10:03 57.7 6.24 10.35
7:25 71.0 7.45 8.02 8:47 63.3 6.47 9.70 10:04 57.8 6.24 10.34
7:26 71.3 7.46 8.02 8:48 63.7 6.50 9.64 10:05 57.9 6.25 10.33
7:27 71.6 7.47 8.01 8:49 63.1 6.46 9.71 10:06 57.8 6.25 10.32
7:28 71.6 7.45 8.03 8:50 62.8 6.44 9.77 10:07 57.8 6.26 10.32
7:29 70.8 7.37 8.16 8:51 62.8 6.43 9.77 10:08 57.8 6.26 10.32
7:30 70.0 7.28 8.34 8:52 62.1 6.35 9.88 10:09 57.9 6.26 10.31
7:31 69.4 7.23 8.45 8:53 61.8 6.31 9.98 10:10 57.9 6.26 10.31
7:32 69.5 7.21 8.48 8:54 62.1 6.34 9.95 10:11 57.8 6.25 10.32
7:33 69.0 7.15 8.58 8:55 62.4 6.37 9.87 10:12 57.8 6.25 10.32
7:34 68.3 7.08 8.70 8:56 62.4 6.37 9.89 10:13 57.7 6.25 10.32
7:35 67.9 7.06 8.75 8:57 62.3 6.36 9.89 10:14 57.9 6.26 10.32
7:36 68.0 7.06 8.76 8:58 62.5 6.37 9.88 10:15 57.8 6.25 10.31
7:37 68.3 7.08 8.72 8:59 62.4 6.38 9.88
7:38 68.5 7.10 8.66
7:39 68.5 7.11 8.65
Brigham Young University, Boiler 6, February 6, 2023
Run 1 Run 2 Run 3
Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %Time NOx ppm CO2 %O2 %
Brigham Young University, Boiler 6, February 6, 2023
Run 1 Run 2 Run 3
Raw Avg 67.27.248.40 Raw Avg 65.46.609.40 Raw Avg 59.0 6.31 10.15
Span 92.9 20.41 20.73 Span 92.9 20.41 20.73 Span 92.9 20.41 20.73
Gas Val 47.19.669.72 Gas Val 47.19.669.72 Gas Val 47.19.669.72
Zeroi -0.1 0.00 -0.02 Zeroi -0.2 0.01 0.01 Zeroi 0.2 0.04 0.02
Zerof -0.2 0.01 0.01 Zerof 0.2 0.04 0.02 Zerof 0.2 0.03 0.04
Spani 47.49.519.63 Spani 48.09.499.70 Spani 47.29.719.74
Spanf 48.09.499.70 Spanf 47.29.719.74 Spanf 48.09.679.74
Corr.66.37.368.44 Corr.64.76.649.40 Corr.58.4 6.28 10.13
Calibration Calibration Calibration
Span 92.9 20.41 20.73 Span 92.9 20.41 20.73 Span 92.9 20.41 20.73
Zero Cal Gas 0.0 0.00 0.00 Zero Cal Gas 0.0 0.00 0.00 Zero Cal Gas 0.0 0.00 0.00
Mid Cal Gas 47.1 9.66 9.72 Mid Cal Gas 47.1 9.66 9.72 Mid Cal Gas 47.1 9.66 9.72
High Cal Gas 92.9 20.41 20.73 High Cal Gas 92.9 20.41 20.73 High Cal Gas 92.9 20.41 20.73
Zero Resp 0.2 0.00 -0.05 Zero Resp 0.2 0.00 -0.05 Zero Resp 0.2 0.00 -0.05
Mid Cal Resp 47.0 9.86 9.75 Mid Cal Resp 47.0 9.86 9.75 Mid Cal Resp 47.0 9.86 9.75
High Cal Resp 93.0 20.05 20.78 High Cal Resp 93.0 20.05 20.78 High Cal Resp 93.0 20.05 20.78 Limits
Ana. Cal. Error (ACE) ACE ACE
Zero Cal Error 0.22% 0.00% 0.24% Zero Cal Error 0.22% 0.00% 0.24% Zero Cal Error 0.22% 0.00% 0.24% 2.0%
Mid Cal Error 0.11% 0.98% 0.14% Mid Cal Error 0.11% 0.98% 0.14% Mid Cal Error 0.11% 0.98% 0.14% 2.0%
High Cal Error 0.11% 1.76% 0.24% High Cal Error 0.11% 1.76% 0.24% High Cal Error 0.11% 1.76% 0.24% 2.0%
System Bias (zero, SB) SB SB
Sys Zero Cal Bias Initial 0.32% 0.00% 0.14% Sys Zero Cal Bias Initial 0.43% 0.05% 0.29% Sys Zero Cal Bias Initial 0.00% 0.20% 0.34% 5.0%
Sys Zero Cal Bias Final 0.43% 0.05% 0.29% Sys Zero Cal Bias Final 0.00% 0.20% 0.34% Sys Zero Cal Bias Final 0.00% 0.15% 0.43% 5.0%
System Zero Drift (D) 0.11% 0.05% 0.14% System Zero Drift 0.43% 0.15% 0.05% System Zero Drift 0.00% 0.05% 0.10% 3.0%
System Bias (upscale, SB) SB SB
System Cal Bias Initial 0.43% 1.71% 0.58% System Cal Bias Initial 1.08% 1.81% 0.24% System Cal Bias Initial 0.22% 0.73% 0.05% 5.0%
System Cal Bias Final 1.08% 1.81% 0.24% System Cal Bias Final 0.22% 0.73% 0.05% System Cal Bias Final 1.08% 0.93% 0.05% 5.0%
System Cal Drift (D) 0.65% 0.10% 0.34% System Cal Drift 0.86% 1.08% 0.19% System Cal Drift 0.86% 0.20% 0.00% 3.0%
CGas = (Cavg - C0) • [Cma / (Cm - C0)]Eq. 7E-5 Eq. 7E-5
C0 = (C0i + C0f) / 2
Cm = (Cmi + Cmf) / 2
ACE = (CDir - Cv) • 100% / CS Eq. 7E-1 Eq. 7E-1
SB =(Cs - CDir) • 100% / CS Eq. 7E-2 Eq. 7E-2
Drift (D) =ABS(SBfinal - Sbinitial)Eq. 7E-4 Eq. 7E-4
STRATIFICATION CHECK FIELD SHEET
Facility Brigham Young University Source Boiler 6
Operator D Kitchen Date 2/4/25
Point 1 Point 2 Point 3
Time O2 Time O2 Time O2
5:51 8.40 5:56 8.41 6:01 8.73
5:52 8.44 5:57 8.39 6:02 8.68
5:53 8.45 5:58 8.34 6:03 8.61
5:54 8.47 5:59 8.35 6:04 8.54
5:55 8.50 6:00 8.33 6:05 8.52
Ave 8.45 8.36 8.62
3 Pt. Mean 8.48 8.48 8.48
% Diff From Mean 0.3 1.3 1.6
- The three sample points were on the center sample port on the north/south traverse line
-If the % diff from mean is less than 5%, one sample point may be used. Use the sampl
closest to the mean value.
-If the % diff from mean is between 5% and 10%, use three sample points at 16.7, 50.0
-If the % diff from mean is greater than 10%, sample 12 points chosed according to EPA

C
APPENDIX C

Sample Recovery

Gas Analysis Data (Method 3A)

D
APPENDIX D

Figure 1. Facility Schematic Representation, Boilers No 4 and 6
Raw Production
Facility:
Stack Identification:
W E
b

Control Unit Type
None
Process Type
Natural Gas, or Oil, Fired Boilers
a
Brigham Young University
6"
35'
48.0" x 84.0"
Boilers 4 and 6
10.0%
300
700
5
18.5'
b: Distance downstream from last disturbance, feet
Estimated Temperature, oF
Estimated Velocity, fpm
Estimated Moisture, percent
a: Distance upstream from next disturbance, feet
 Stack Inside Diameter, inches
g: Distance of Sample Level to Ground, feet
Number of Ports
ag
Figure 1. Facility Schematic Representation

E
APPENDIX E

Calibration of the console dry gas meter(s), pitot tubes, nozzles diameters, and temperature
sensors were carried out in accordance with the procedures outlined in the Quality Assurance
Handbook. The appropriate calibration data are presented in the following pages.

Figure 2. Schematic Representation of Method 4 Sampling Train
Figure 3. Schematic of Gas Analyzer Sampling Train

Meter Box Calibration Data and Calculations Forms
Post-test Dry Gas Meter Calibration Data Forms
Type S Pitot Tube Inspection Data
Sample Box Temperature Sensor Calibration
Calibration Gas Certifications
NOx Converter Efficiency Check

Figure 2. Schematic of Method 4 Sampling Train
Figure 3. Schematic of Gas Analyzer Sampling Train.
MeshFilter
StackWall
Sample Probe
Heated Sample Line
Bias Valve
Bias Line
Sample Line
CalibrationGases
CalibrationGas Lines
Analyzer
Analyzer
Analyzer
Analyzer
Flowmeters
By-Pass Flowmeter
Sample Exhaust
Valve
Valve
SampledGas Manifold
Exhaust
Data AquisitionSystem
Sample Pump
Water
PeristalicPump
Peltier Cooler
METHOD 5 DRY GAS METER CALIBRATION USING CRITICAL ORIFICES
1) Select three critical orifices to calibrate the dry gas meter which bracket the expected operating range.
2) Record barometric pressure before and after calibration procedure.
3) Run at tested vacuum (from Orifice Calibration Report), for a period of time
necessary to achieve a minimum total volume of 5 cubic feet.
4) Record data and information in the GREEN cells, YELLOW cells are calculated.
TECHNICIAN:INITIAL FINAL AVG (Pbar)
DATE:12/12/24 METER SERIAL #:300315 BAROMETRIC PRESSURE (in Hg):25.27 25.27 25.27 IF Y VARIATION EXCEEDS 2.00%,
METER PART #:Console 3 CRITICAL ORIFICE SET SERIAL #:1453S EQUIPMENT ID #:ORIFICE SHOULD BE RECALIBRATED
K'TESTED TEMPERATURES °F ELAPSED
FACTOR VACUUM DGM READINGS (FT3)AMBIENT DGM INLET DGM OUTLET DGM TIME (MIN)DGM DH (1)(2)(3)Y
ORIFICE #RUN #(AVG)(in Hg)INITIAL FINAL NET (Vm)INITIAL FINAL INITIAL FINAL AVG q (in H2O)Vm (STD)Vcr (STD)Y VARIATION (%)DH@
1 0.8137 11 99.707 105.165 5.458 70 88 89 91 95 90.8 5.000 2.90 4.4573 4.4671 1.002 1.669
2 0.8137 11 105.165 110.643 5.478 70 89 90 95 97 92.8 5.000 2.90 4.4575 4.4671 1.002 1.663
3 0.8137 11 110.643 116.127 5.484 70 90 91 97 98 94.0 5.000 2.90 4.4523 4.4671 1.003 1.659
AVG = 1.003 0.52
1 0.5317 13 65.250 70.833 5.583 68 67 70 67 73 69.3 8.000 1.20 4.7215 4.6792 0.991 1.669
2 0.5317 13 70.833 76.081 5.248 69 70 74 73 77 73.5 7.500 1.20 4.4028 4.3826 0.995 1.658
3 0.5317 13 76.081 81.348 5.267 70 74 77 77 81 77.3 7.500 1.20 4.3879 4.3785 0.998 1.650
AVG = 0.995 -0.26
1 0.3307 13 82.051 87.346 5.295 70 77 82 81 83 80.8 12.000 0.45 4.3731 4.3572 0.996 1.586
2 0.3307 13 87.346 92.464 5.118 70 82 85 83 86 84.0 11.500 0.45 4.2017 4.1757 0.994 1.576
3 0.3307 13 92.464 97.832 5.368 70 85 88 86 89 87.0 12.000 0.45 4.3827 4.3572 0.994 1.568
AVG = 0.995 -0.26
AVERAGE DRY GAS METER CALIBRATION FACTOR, Y = 0.997
AVERAGE DH@ = 1.633
(1)=Net volume of gas sample passed through DGM, corrected to standard conditions
K1 =17.64 oR/in. Hg (English), 0.3858 oK/mm Hg (Metric)
Tm =Absolute DGM avg. temperature (oR - English, oK - Metric) DH@ = 0.75 q DH Vm(std)
Vcr(std) Vm
(2)=Volume of gas sample passed through the critical orifice, corrected to standard conditions
Tamb =Absolute ambient temperature (oR - English, oK - Metric)
Average K' factor from Critical Orifice Calibration REFERENCE IN OUT
(3)=DGM calibration factor 32 33 32
62 63 63
204 205 205
TEMPERATURE SENSORS oF
2025 Pre-Calibration
Console #3
30
19
12
M. McNamara
ENVIRONMENTAL SUPPLY COMPANY
USING THE CRITICAL ORIFICES AS CALIBRATION STANDARDS:
The following equations are used to calculate the standard volumes of air passed through the DGM, Vm (std), and the critical orifice, Vcr(std), and the DGM calibration factor, Y. These equations are automatically calculated in the spreadsheet above.
()2 ()
METHOD 5 DRY GAS METER CALIBRATION USING CRITICAL ORIFICES
1) Select three critical orifices to calibrate the dry gas meter which bracket the expected operating range.
2) Record barometric pressure before and after calibration procedure.3) Run at tested vacuum (from Orifice Calibration Report), for a period of time
necessary to achieve a minimum total volume of 5 cubic feet.
4) Record data and information in the GREEN cells, YELLOW cells are calculated.
TECHNICIAN:INITIAL FINAL AVG (Pbar)
DATE:12/19/2024 METER SERIAL #:26144 BAROMETRIC PRESSURE (in Hg):25.80 25.80 25.80 IF Y VARIATION EXCEEDS 2.00%,
METER PART #:Console 5 CRITICAL ORIFICE SET SERIAL #:1453S EQUIPMENT ID #:ORIFICE SHOULD BE RECALIBRATED
K'TESTED TEMPERATURES °F ELAPSED
FACTOR VACUUM DGM READINGS (FT3)AMBIENT DGM INLET DGM OUTLET DGM TIME (MIN)DGM DH (1)(2)(3)Y
ORIFICE #RUN #(AVG)(in Hg)INITIAL FINAL NET (Vm)INITIAL FINAL INITIAL FINAL AVG q (in H2O)Vm (STD)Vcr (STD)Y VARIATION (%)DH@
1 0.8137 13 0.416 5.713 5.297 71 87 91 78 79 83.8 4.75 2.80 4.4715 4.3287 0.968 1.601
2 0.8137 13 5.713 11.030 5.317 71 90 96 79 80 86.3 4.76 2.80 4.4678 4.3378 0.971 1.594
3 0.8137 13 11.030 16.357 5.327 71 94 98 80 82 88.5 4.76 2.80 4.4578 4.3378 0.973 1.587
AVG = 0.971 -1.90
1 0.5317 13 83.552 88.669 5.117 70 77 81 73 74 76.3 7.26 1.10 4.3591 4.3273 0.993 1.484
2 0.5317 13 88.669 93.841 5.172 70 80 85 75 76 79.0 7.36 1.10 4.3833 4.3869 1.001 1.476
3 0.5317 13 93.841 99.045 5.204 70 84 89 76 79 82.0 7.26 1.10 4.3860 4.3273 0.987 1.468
AVG = 0.993 0.39
1 0.3307 14 17.300 22.400 5.100 70 93 92 82 85 88.0 11.51 0.41 4.2429 4.2670 1.006 1.396
2 0.3307 14 22.400 28.298 5.898 70 91 93 84 87 88.8 13.26 0.41 4.9001 4.9157 1.003 1.394
3 0.3307 14 28.298 33.427 5.129 70 92 96 86 88 90.5 11.51 0.41 4.2476 4.2670 1.005 1.390
AVG = 1.004 1.51
AVERAGE DRY GAS METER CALIBRATION FACTOR, Y = 0.990
AVERAGE DH@ = 1.488
(1)=Net volume of gas sample passed through DGM, corrected to standard conditions
K1 =17.64 oR/in. Hg (English), 0.3858 oK/mm Hg (Metric)
Tm =Absolute DGM avg. temperature (oR - English, oK - Metric) DH@ = 0.75 q DH Vm(std)
Vcr(std) Vm
(2)=Volume of gas sample passed through the critical orifice, corrected to standard conditions
Tamb =Absolute ambient temperature (oR - English, oK - Metric)
K' = Average K' factor from Critical Orifice Calibration REFERENCE IN OUT
(3)=DGM calibration factor 32 33 32
72 73 73
203 203 202
12
TEMPERATURE SENSORS oF
2025 Pre-Calibration
A. Kitchen
Console #5
30
19
ENVIRONMENTAL SUPPLY COMPANY
USING THE CRITICAL ORIFICES AS CALIBRATION STANDARDS:The following equations are used to calculate the standard volumes of air passed through the DGM, Vm (std), and the critical orifice,
Vcr (std), and the DGM calibration factor, Y. These equations are automatically calculated in the spreadsheet above.
()2 ()
METHOD 5 DRY GAS METER CALIBRATION USING CRITICAL ORIFICES
1) Select three critical orifices to calibrate the dry gas meter which bracket the expected operating range.
2) Record barometric pressure before and after calibration procedure.3) Run at tested vacuum (from Orifice Calibration Report), for a period of time
necessary to achieve a minimum total volume of 5 cubic feet.
4) Record data and information in the GREEN cells, YELLOW cells are calculated.
TECHNICIAN:INITIAL FINAL AVG (Pbar)
DATE:2/6/25 METER SERIAL #:300315 BAROMETRIC PRESSURE (in Hg):25.35 25.35 25.35 IF Y VARIATION EXCEEDS 2.00%,
METER PART #:Console 3 CRITICAL ORIFICE SET SERIAL #:1453S EQUIPMENT ID #:ORIFICE SHOULD BE RECALIBRATED
K'TESTED TEMPERATURES °F ELAPSED
FACTOR VACUUM DGM READINGS (FT3)AMBIENT DGM INLET DGM OUTLET DGM TIME (MIN)DGM DH (1)(2)(3)Y
ORIFICE #RUN #(AVG)(in Hg)INITIAL FINAL NET (Vm)INITIAL FINAL INITIAL FINAL AVG q (in H2O)Vm (STD)Vcr (STD)Y VARIATION (%)DH@
1 0.5317 13 33.400 39.078 5.678 80 65 71 64 72 68.0 8.500 1.20 4.8284 4.9316 1.021 1.705
2 0.5317 13 39.078 44.139 5.061 80 71 75 72 79 74.3 7.500 1.20 4.2533 4.3514 1.023 1.685
3 0.5317 13 44.139 50.450 6.311 80 75 79 79 83 79.0 9.330 1.20 5.2571 5.4132 1.030 1.670
AVG = 1.025 0.00
1
2
3
AVG =
1
2 0.00
3 0.00
AVG =
AVERAGE DRY GAS METER CALIBRATION FACTOR, Y = 1.025
AVERAGE DH@ = 1.687
(1)=Net volume of gas sample passed through DGM, corrected to standard conditions
K1 =17.64 oR/in. Hg (English), 0.3858 oK/mm Hg (Metric)
Tm =Absolute DGM avg. temperature (oR - English, oK - Metric) DH@ = 0.75 q DH Vm(std)
Vcr(std) Vm
(2)=Volume of gas sample passed through the critical orifice, corrected to standard conditions
Tamb =Absolute ambient temperature (oR - English, oK - Metric)
Average K' factor from Critical Orifice Calibration REFERENCE IN OUT
(3)=DGM calibration factor 32 33 32
62 63 63
204 205 205
TEMPERATURE SENSORS oF
BYU Provo
M. McNamara
Console #3
19
ENVIRONMENTAL SUPPLY COMPANY
USING THE CRITICAL ORIFICES AS CALIBRATION STANDARDS:
The following equations are used to calculate the standard volumes of air passed through the DGM, Vm(std), and the critical orifice,
Vcr (std), and the DGM calibration factor, Y. These equations are automatically calculated in the spreadsheet above.
()2 ()
METHOD 5 DRY GAS METER CALIBRATION USING CRITICAL ORIFICES
1) Select three critical orifices to calibrate the dry gas meter which bracket the expected operating range.
2) Record barometric pressure before and after calibration procedure.3) Run at tested vacuum (from Orifice Calibration Report), for a period of time
necessary to achieve a minimum total volume of 5 cubic feet.
4) Record data and information in the GREEN cells, YELLOW cells are calculated.
TECHNICIAN:INITIAL FINAL AVG (Pbar)
DATE:02/06/25 METER SERIAL #:26144 BAROMETRIC PRESSURE (in Hg):25.35 25.35 25.35 IF Y VARIATION EXCEEDS 2.00%,
METER PART #:Console 5 CRITICAL ORIFICE SET SERIAL #:1453S EQUIPMENT ID #:ORIFICE SHOULD BE RECALIBRATED
K'TESTED TEMPERATURES °F ELAPSED
FACTOR VACUUM DGM READINGS (FT3)AMBIENT DGM INLET DGM OUTLET DGM TIME (MIN)DGM DH (1)(2)(3)Y
ORIFICE #RUN #(AVG)(in Hg)INITIAL FINAL NET (Vm)INITIAL FINAL INITIAL FINAL AVG q (in H2O)Vm (STD)Vcr (STD)Y VARIATION (%)DH@
1 0.5317 13 57.300 62.606 5.306 76 77 80 81 85 80.8 7.50 1.10 4.4043 4.3677 0.992 1.514
2 0.5317 13 62.606 67.928 5.322 76 80 85 85 92 85.5 7.50 1.10 4.3791 4.3677 0.997 1.501
3 0.5317 13 67.928 73.108 5.180 76 85 87 92 96 90.0 7.25 1.10 4.2274 4.2221 0.999 1.489
AVG = 0.996 0.00
1
2
3
AVG =
1
2
3
AVG =
AVERAGE DRY GAS METER CALIBRATION FACTOR, Y = 0.996
AVERAGE DH@ = 1.502
(1)=Net volume of gas sample passed through DGM, corrected to standard conditions
K1 =17.64 oR/in. Hg (English), 0.3858 oK/mm Hg (Metric)
Tm =Absolute DGM avg. temperature (oR - English, oK - Metric) DH@ = 0.75 q DH Vm(std)
Vcr(std) Vm
(2)=Volume of gas sample passed through the critical orifice, corrected to standard conditions
Tamb =Absolute ambient temperature (oR - English, oK - Metric)
K' = Average K' factor from Critical Orifice Calibration REFERENCE IN OUT
(3)=DGM calibration factor
TEMPERATURE SENSORS oF
Post CalibrationBYU Provo
M McNamara
Console #5
19
ENVIRONMENTAL SUPPLY COMPANY
USING THE CRITICAL ORIFICES AS CALIBRATION STANDARDS:The following equations are used to calculate the standard volumes of air passed through the DGM, Vm (std), and the critical orifice,
Vcr (std), and the DGM calibration factor, Y. These equations are automatically calculated in the spreadsheet above.
()2 ()
Type S Pitot Tube Inspection Data
Date:Pitot Tube Identification:
Technician:
Dt=0.375 Is PA = PB ?
Is 1.05 • Dt  PA & PB  1.50 • Dt ?
PA = 0.424
PB =0.424
a1 < 10o a1 = o
a2 < 10o a2 = o
b1 < 5o b1 = o
b2 < 5o b2 = o
Z  0.125 in.Z = in.
W W  0.03125 in.W = in.
W > 3 inches W = in.
Z > 3/4 inch Z = in.
Y ≥ 3 inches Y = in.
The pitot tube meets the specifications for a calibration factor of 0.84?Yes
Reference:
TemperatureSource Reference Sensor
(Medium)(oF)(oF)
Probe AIR 62 62
AIR 64 62
ICE WATER 33 33
BOIL WATER 204 203
SILICONE OIL
Heat Check 248
Temperature Sensor Calibration
2
0
1Stack
Omega CL3512A
Probe Yes
Yes
Continuity Check
Temperature TemperatureDifference
(oF)
0
in.
in.
Yes
Yes
0.030
9.5
0.875
3 1/4
1/2/25 51 G-4
A. Kitchen
in.
0.015
2
1
0
1
b2
b1
B
A
w
Dt
PA
PB
Date:1/2/25 Calibrator:Reference:
Temperature Temperature
Source Difference
(Medium)(oF)
Water -1
Water -2
Water -1
Water 2
Water -1
Water -2
Water -2
Water 2
Water -1
Water 0
Water 0
Water 1
Water 0
Water 2
Water 0
Water 1
Water -1
Water 2
Water 0
Water -1
Water -1
Water 2
Water -1
Water 1
Water 0
Water 1
Water 1
Water 0
Water 1
Water 0
Water 1
Water -1
Water 0
Water -2
Water 1
Water -1
Water 1
Water 0
Water 1
Water 1
Water 0
Water -1
Water 0
Water -2
Water 1
Water -1
Water 1
Water 0
D
E
Oven 33 32
205 207F
Oven (4)
Oven (3)
Oven (4)
TETCO
Sample Box Temperature Sensor Calibration
B
C 203 203
33 33
33 31
204
33 32
Alan Kitchen Omega CL3512A
Unit ID Reference
(oF)
Sensor
(oF)
Temperature
33
203
33 34
203Impinger Out B
Impinger Out C 33 34
203 202
203
Impinger Out A 33 34
203
Impinger Out D 33 33
203 201
Impinger Out E 33 34
203 202
Impinger Out F 33 34
202
204
206
205 206
204 205
33
33
Impinger Out G
203 203
Oven (3)33
205 207
33 33
205Oven (4)
203
A
207205
32
Oven (3)33 32
Oven (4)
Thermocouple
Location
205 203
206
33
G
H
Oven (3)33 32
204 206
Oven (4)33
203
Oven 33 33
203 204
Oven 33 32
32
204 202
Oven (3)
204
33 34
Impinger Out K 33 34
203 203
33 34
Impinger Out J
Impinger Out H
Impinger Out I
33
201
33
202
33
203
33
203
203
.. Making our world
more productive ••
I
[!]
Linde Gas & Eauioment Inc .
5700 S. Alameda Street
Los Angeles, CA 90058
Tel: [phone]
Fax: [phone]
Customer & Or~er Information:
' LGEPKG BISMARCK ND HS
820 E FRONT AVE,
BISMARCK, ND 58504-5647
Linde Order Number: 72233703
Gustomer PO Number: 80239175
Certificate Issuance Date: 10/19/2022
Certification Date: 10/18/2022
Lot Number: N70086228605
Part Number: NI 5;5cE-AS
DocNumber: 621387
CERTIFICATE OF ANALYSIS
Nitrogen, 5.5 Continuous Emission Monitoring Zero
Sp¢cification
Analytical Analytical Analytical
Analytes Results Reference Uncertainty
Nitrogen ~ S9.9995 % ~ 99.9995 % 5 N/A
Carbon Dioxid~ S 1: ppm S 0.5 ppm 3 ±10%
Carbon Monoxide s Oi'5 ppm S 0.5 ppm 3 ±15%
Total Hydrocarbons S 0.1 ppm S 0.1 ppm 6 ±15%
Oxides of Nitrogen S 0.1 ppm S 0.1 ppm 7 ±15%
Oxygen S 0.5 ppm S 0.5 ppm 2 ± 15%
Sulfur Dioxide S 0.1 ppm S 0.1 ppm 1 ±15%
Water S 2 ppm S 1.0 ppm 4 ± 10%
.·· Cylinder Style: AS Fill Oat~: 10/13/2022 Filling Method: Pressure/Temperature
,----"_c,~:,;,Gylfnder-Pressurer@----ro·F:'""200(tpsil'f'---~ ·Analysis Date: 10/1772022 ----. -~-------~----------.----.--
Cylinder Volume: 142 ft3
Valve Outlet Connection: CGA 580
Cylinder Number(s): ALM-055870, EB0024542, CC200224, DT0041799, CC198178, CC269928,
CC196415, DT0017904, DT0011356, CC102834, DT0025700, CC187407,
CC138306,CC241317,CC101654
1
~; ALM-055870 ~
Key to Analytical Techniques:
Reference Analytical Instrument -Analytical Principle
Ametek 921CE S/N AW-921-S321 -UV Spectrometry
2 Delta F DF-550 Nanotrace -Electrolytic Cell/Electrochemical
3 Horiba Instruments Inc. GA-360E -NDIR
4
5
6
7
Meeco Aquavolt PLUS -Specific Water Analyzer
N/A -By Difference of Typical Impurities
Rosemount/Beckman 400A -FID Total Hydrocarbon Analyzer
Thermo Electron 42i-LS S/N 1030645077 -Chemiluminescence
Approved Signer: Ying Yu
This analysis of the product described herein was prepared by Linde Gas & Equipment lnc:using instruments whose calibration is certified using Linde Gas & Equipment Inc. Reference Materials
which are traceable to the International System of Units (SI) through either weights traceable to the National Institute of Standards and Technology (NIST) or Measurement Canada, or through NIST
Standard Reference Materials or equivalent where available.
Note: All expressions for concentration (e.g.,% or ppm} are for gas phase, by mole unless otherwise noted. Analytical uncertanity is expressed as a Relative% unless otherwise noted.
IMPORTANT
The information contained herein has been prepared at your request by personnel within Linde Gas & Equipment Inc. While we believe the information is accurate within the limits of the analytical
methods employed and is complete to the extent of the specific analyses performed, we make no warranty or representation as to the suitability of the use of the information for any particular purpose.
The information is offered with the understanding that any use of the information is at the sole discretion and risk of the user. In no event shall liability of Linde Gas & Equipment Inc. arising out of the
use of the information contained herein exceed the fee established for providing such information.
Date Time Output
1/11/2023 9:31 47.37 Concentration of Certified Gas used 92.9 ppmdv NOx
1/11/2023 9:32 47.55 Diluted with air at approx 1:1
1/11/2023 9:33 47.55 Instrument Span 92.9 ppmdv
1/11/2023 9:34 47.61
1/11/2023 9:35 47.65 NOxPeak 47.8
1/11/2023 9:36 47.69 NOxFinal 47.6
1/11/2023 9:37 47.76 (Eq. 7E-9)EffNO2 0.6 %
1/11/2023 9:38 47.78
1/11/2023 9:39 47.82 Average Reading 47.7 ppmdv
1/11/2023 9:40 47.82
1/11/2023 9:41 47.75
1/11/2023 9:42 47.67
1/11/2023 9:43 47.69
1/11/2023 9:44 47.67
1/11/2023 9:45 47.69
1/11/2023 9:46 47.68
1/11/2023 9:47 47.61
1/11/2023 9:48 47.66
1/11/2023 9:49 47.67
1/11/2023 9:50 47.61
1/11/2023 9:51 47.58
1/11/2023 9:52 47.62
1/11/2023 9:53 47.67
1/11/2023 9:54 47.68
1/11/2023 9:55 47.64
1/11/2023 9:56 47.65
1/11/2023 9:57 47.72
1/11/2023 9:58 47.61
1/11/2023 9:59 47.58
1/11/2023 10:00 47.55

END
40 CFR 60 Appendix A-4, Method 7E, Section 16.2.2
Fill a Tedlar bag approximately half full with either ambient air, pure oxygen, or an oxygen standard gas with at
least 19.5 percent by volume oxygen content. Fill the remainder of the bag with mid-level NO in nitrogen
calibration gas...
Immediately attach the bag to the inlet of the NOx analyzer (or external converter if used)… Measure the NOx
concentration for a period of 30 minutes. If the NOx concentration drops more than 2 percent absolute from the
peak value observed, then the NO2 converter has failed to meet the criteria of this test. Take corrective action.
The highest NOx value observed is considered to be NOxPeak. The final NOx value observed is considered to be
NOxFinal.
NOx Converter Efficiency Test

F
APPENDIX F

The testing protocol and other correspondence related to the tests are included here.

Stack Test Report Submission
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Division of Air Quality, Complaince Branch
12/19/24, 3:54 PM DAQ Stack Test Submission
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1
NOX COMPLIANCE TEST PROTOCOL
BRIGHAM YOUNG UNIVERSITY, PROVO, UTAH
CENTRAL HEATING PLANT
BOILERS #4 AND #6

Project Organization and Responsibility

The following personnel and the testing contractor are presently anticipated to be involved in the
testing program. Utah Department of Environmental Quality, Division of Air Quality (DAQ)
may have their own personnel or contractor to observe all phases including the process.

Company Contacts

Brigham Young University Brian Harris 801 422-5438
Physical Plant Department BYU Risk Management
225 BRWB Environmental Manger
Provo, UT 84602

Test Contractor
TETCO Dean A. Kitchen 801 492-9106
391 East 620 South
American Fork, UT 84003

During these tests only Brigham Young University (BYU) personnel listed above or assigned
personnel from the operation are authorized to answer or obtain answers to pertinent questions
on the process conditions or the test protocol.

Test Schedule

It is currently planned to complete this test project the week of February 3, 2024. The testing
crew will arrive and set up the equipment on February 3rd. It is anticipated that testing will
begin the morning of February 4th and continue until all testing has been completed. A pretest
meeting may be held at the request of BYU or DAQ.

Project Description

This test project will be conducted to comply with the requirements of BYU’s Approval Order,
DAQE-AN107900021-23, dated May 24, 2023, which requires testing Boilers #4 and #6 for

2
NOx emissions once every three years. Testing will be performed according to EPA Methods 1-4,
and 7E and will include accumulating process and production data.

Test Procedures

Three separate 1-hr test runs will be completed on each boiler. Testing will be conducted
according to EPA Methods 1-4 and 7E, and as specified in 40 CFR 60, Appendix A. Specific
test procedures are as follows:

EPA Methods 1-4

1. Boilers #4 and #6 have a common exhaust duct with inside dimensions of 48 inches by
84 inches. The sample ports are located 18.5 feet downstream and 6 feet upstream from
any flow disturbance and conform to EPA Method 1. Sample points will be selected
according to EPA Method 1 for a non-particulate traverse.

2. EPA Method 2 will be used to determine gas stream velocity. Type “S” pitot tubes will
be used with a Cp factor of 0.84. Dual inclined/vertical manometers with graduations of
0.01 inches of water will be used. If flows are below 0.05 inches of water a more
sensitive manometer will be used with graduations marks of 0.005 inches of water.
Direction of gas flow will be checked for cyclonics prior to testing.

3. A barometer will be used to measure the barometric pressure. It is periodically checked
against a mercury barometer. Prior to testing it will be checked to ensure an accurate
barometric pressure.

4. EPA Method3A will be used to determine the gas stream dry molecular weight.

5. Each test run will be at least 60 minutes in duration and each Method 4 test run will be
sun sufficient to sample at least 21 dscf as required by Method 4.

6. The probe liners will be 316 stainless-steel.

7. Preparation and clean-up by the contractor will be performed in the contractor's testing
trailer.

8. If plant maintenance or operating problems arise during the test, the test may be stopped.
This determination will be made by the Brigham Young University representatives or
operating personnel in consultation with agency representatives.

9. Current calibration data is submitted in Appendix A of this protocol. Any equipment
calibration that fall past due prior to the test date will be recalibrated prior to use.

3
Gaseous Analyzer Measurements

The following procedures will be used for the Method 7E tests:

1. Gaseous analyzers will be used to measure the NOx and CO concentrations during the
emissions test project. It is planned to run the NOx and CO analyzers on a 0-100 ppm
range. EPA Protocol 1 gases will be used as calibration standards with dry nitrogen as a
zero gas.

2. A gaseous analyzer will be used to measure the O2 and CO2 concentrations during the
emissions test project. It is planned to run the O2 and CO2 analyzers on a 0-10, or 0-20
percent range. EPA Protocol 1 gases would be used as calibration standards with dry
nitrogen as a zero gas.

3. The gas analyzer sampling train will consist of the following: an in-stack glass fiber
filter, heated stainless-steel probe, Teflon heated sampling line to the water removal
system, water removal system, Teflon transport lines, gas manifold, and out of stack
Teflon filter after the gas manifold but prior to analyzers. The sampling train is built so
that the sampled gas only comes in contact with Teflon, stainless steel, and glass.

4. The number of sample points for the gas analyzer sampling train will be determined
according to the results of a stratification check as per Method 7E, section 8.1.2.

5 The NOx converter efficiency check will be completed according to Method 7E, section
16.2.2.

6. Bias checks, calibration drift, zero drift and calibration error will follow the specified
guidelines of EPA Method 7E. Interference responses were determined in the factory
and no alterations have been made; therefore, factory specifications are satisfactory.

7. A data logger will be used to record measured concentrations. Gas analyzer data during
port changes will not be considered valid data.

Test Area

The test area shall include the Heating Plant control room, main floor, and stack areas, and the
area around the contractors testing trailer.

Process Data

Process parameters are available via computer in the Heating Plant control room. Pertinent
process parameters will be made available to DAQ personnel and included in the test report.

4

Quality Assurance

All testing and analysis in these tests will be conducted according to Methods 1-4, 7E, and
appropriate sections of the EPA Quality Assurance Handbook for Air Pollution Measurement
Systems Vol. III.

Reporting

Complete copies of raw data, calculations and summary of the tests will be included in the
report. All process and production data will be recorded and retained for inspection and
copying by DAQ. The contractor will furnish copies of the test report to BYU.

5
Appendix A

Calibration Data

METHOD 5 DRY GAS METER CALIBRATION USING CRITICAL ORIFICES
1) Select three critical orifices to calibrate the dry gas meter which bracket the expected operating range.
2) Record barometric pressure before and after calibration procedure.
3) Run at tested vacuum (from Orifice Calibration Report), for a period of time
necessary to achieve a minimum total volume of 5 cubic feet.
4) Record data and information in the GREEN cells, YELLOW cells are calculated.
TECHNICIAN:INITIAL FINAL AVG (Pbar)
DATE:8/15/24 METER SERIAL #:28152 BAROMETRIC PRESSURE (in Hg):25.58 25.58 25.58 IF Y VARIATION EXCEEDS 2.00%,
METER PART #:Console 9 CRITICAL ORIFICE SET SERIAL #:1453S EQUIPMENT ID #:ORIFICE SHOULD BE RECALIBRATED
K'TESTED TEMPERATURES °F ELAPSED
FACTOR VACUUM DGM READINGS (FT3)AMBIENT DGM INLET DGM OUTLET DGM TIME (MIN)DGM DH (1)(2)(3)Y
ORIFICE #RUN #(AVG)(in Hg)INITIAL FINAL NET (Vm)INITIAL FINAL INITIAL FINAL AVG q (in H2O)Vm (STD)Vcr (STD)Y VARIATION (%)DH@
1 0.8137 11 46.804 52.225 5.421 86 83 83 82 82 82.5 5.08 2.90 4.5492 4.5291 0.996 1.724
2 0.8137 11 52.225 57.990 5.765 86 84 84 82 82 83.0 5.40 2.90 4.8334 4.8142 0.996 1.723
3 0.8137 11 57.990 63.656 5.666 86 84 84 82 82 83.0 5.30 2.90 4.7504 4.7180 0.993 1.723
AVG = 0.995 -1.95
1 0.5317 10 28.785 33.857 5.072 85 84 85 82 82 83.3 7.48 1.15 4.2292 4.3573 1.030 1.588
2 0.5317 10 33.857 39.004 5.147 86 83 85 82 82 83.0 7.58 1.15 4.2937 4.4156 1.028 1.592
3 0.5317 10 39.004 44.106 5.102 86 82 82 84 86 83.5 7.52 1.15 4.2523 4.3772 1.029 1.590
AVG = 1.029 1.45
1 0.3307 12 93.392 98.648 5.256 80 81 82 78 79 80.0 12.31 0.45 4.4002 4.4810 1.018 1.598
2 0.3307 12 98.648 103.719 5.071 80 82 82 79 80 80.8 11.87 0.45 4.2394 4.3234 1.020 1.596
3 0.3307 12 103.719 108.901 5.182 80 82 83 80 80 81.3 12.14 0.45 4.3282 4.4199 1.021 1.594
AVG = 1.020 0.50
AVERAGE DRY GAS METER CALIBRATION FACTOR, Y = 1.015
AVERAGE DH@ = 1.637
(1)=Net volume of gas sample passed through DGM, corrected to standard conditions
K1 =17.64 oR/in. Hg (English), 0.3858 oK/mm Hg (Metric)
Tm =Absolute DGM avg. temperature (oR - English, oK - Metric) DH@ = 0.75 q DH Vm(std)
Vcr(std) Vm
(2)=Volume of gas sample passed through the critical orifice, corrected to standard conditions
Tamb =Absolute ambient temperature (oR - English, oK - Metric)
K' = Average K' factor from Critical Orifice Calibration REFERENCE IN OUT
(3)=DGM calibration factor 32 33 32
72 73 73
203 203 202
12
TEMPERATURE SENSORS oF
2024 Pre-Calibration August
D Kitchen
Console #9
30
19
ENVIRONMENTAL SUPPLY COMPANY
USING THE CRITICAL ORIFICES AS CALIBRATION STANDARDS:
The following equations are used to calculate the standard volumes of air passed through the DGM, Vm (std), and the critical orifice, Vcr (std), and the DGM calibration factor, Y. These equations are automatically calculated in the spreadsheet above.
()2 ()
Type S Pitot Tube Inspection Data
Date:Pitot Tube Identification:
Technician:
Dt=0.375 Is PA = PB ?
Is 1.05 • Dt  PA & PB  1.50 • Dt ?
PA = 0.476
PB =0.476
a1 < 10o a1 = o
a2 < 10o a2 = o
b1 < 5o b1 = o
b2 < 5o b2 = o
Z  0.125 in.Z = in.
W W  0.03125 in.W = in.
W > 3 inches W = in.
Z > 3/4 inch Z = in.
Y ≥ 3 inches Y = in.
The pitot tube meets the specifications for a calibration factor of 0.84?Yes
Reference:
TemperatureSource Reference Sensor
(Medium)(oF)(oF)
Probe AIR 63 62
AIR 64 62
ICE WATER 33 34
BOIL WATER 204 204
SILICONE OIL
1/16/2024 51 G
M. McNamara
in.
0.002
2
0
1
1
1
in.
in.
Yes
Yes
0.004
5
1
3 1/2
Heat Check 248
Temperature Sensor Calibration
2
1
0Stack
Omega CL3512A
Probe Yes
Yes
Continuity Check
Temperature TemperatureDifference
(oF)
b2
b1
B
A
w
Dt
PA
PB
Type S Pitot Tube Inspection Data
Date:Pitot Tube Identification:
Technician:
Dt=0.375 Is PA = PB ?
Is 1.05 • Dt  PA & PB  1.50 • Dt ?
PA = 0.453
PB =0.453
a1 < 10o a1 = o
a2 < 10o a2 = o
b1 < 5o b1 = o
b2 < 5o b2 = o
Z  0.125 in.Z = in.
W W  0.03125 in.W = in.
W > 3 inches W = in.
Z > 3/4 inch Z = in.
Y ≥ 3 inches Y = in.
The pitot tube meets the specifications for a calibration factor of 0.84?Yes
Reference:
TemperatureSource Reference Sensor
(Medium)(oF)(oF)
Probe AIR 64 65
AIR 64 64
ICE WATER 33 33
BOIL WATER 204 204
SILICONE OIL
1/16/2024 60 G-1
M. McNamara
in.
0.012
3
1
2
2
1
in.
in.
Yes
Yes
0.004
5
1.5
3 3/4
Heat Check 248
Temperature Sensor Calibration
0
0
0Stack
Omega CL3512A
Probe Yes
Yes
Continuity Check
Temperature TemperatureDifference
(oF)
b2
b1
B
A
w
Dt
PA
PB
Date:1/2/24 Calibrator:Reference:
Temperature Temperature
Source Difference
(Medium)(oF)
Water 0
Water -2
Water 0
Water -2
Water 0
Water -1
Water 0
Water -2
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water -1
Water 0
Water -1
Water 0
Water 0
Water 0
Water 0
Water 0
Water -1
Water 0
Water -1
Water 0
Water 0
Water 1
Water 0
Water 0
Water -2
Water 0
Water -1
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
Water 0
202
33 33
Impinger Out K 33 33
203 203
33 33
Impinger Out J
Impinger Out H
Impinger Out I
33
203
33
203
33
203
33
203
203
201
33
G
H
Oven (3)33 33
203 203
Oven (4)33
203
Oven 33 33
203 203
Oven 33 33
33
203 202
Oven (3)
A
201203
33
Oven (3)33 33
Oven (4)
Thermocouple
Location
203 201
Impinger Out F 33 33
203
203
203
203 202
203 203
33
33
Impinger Out G
203 201
Oven (3)33
203 203
33 33
203Oven (4)
203
Impinger Out D 33 33
203 203
Impinger Out E 33 34
203 203
203
33 33
203Impinger Out B
Impinger Out C 33 33
203 202
202
Impinger Out A 33 33
203
Oven (3)
Oven (4)
TETCO
Sample Box Temperature Sensor Calibration
B
C 203 203
33 33
33 33
203
33 33
Xuan N. Dang Omega CL3512A
Unit ID Reference
(oF)
Sensor
(oF)
Temperature
33
D
E
Oven 33 33
203 202F
Oven (4)
Making our world
more productive
DocNumber: 553767
~ RI
Certificate Issuance Date: 0712812023
Linde Order Number: 11400950
Linde Gas & Equipment Inc;
5700 S. Alameda Street
Los Angeles CA 90058
Tel: [phone]
Fax: [phone]
PGVP ID: F22023
Fill Date: 07112/2023
Lot Number: 70086319309
Customer & Order Information
TETCO
391 E 620 S Part Number: NI CO47.5MN1EAS
Customer PO Number: DEAN
Cylinder Style & Outlet: AS CGA 660
AMERICAN FORK UT 84003 Cylinder Pressure and Volume: 2000 psig 140 ft3
Expiration Date:
Cylinder Number:
For Refe,rence Only:
47.5 ppm
47.1 ppm
Balance
NOx47.3ppm
Certified Concentration
07/28/2026
CC121457
Carbon monoxide
Nitric oxide
Nitrogen
NIST Traceable
Expanded Uncertainty
±0.2 ppm
±0.2 ppm
Certification InJ.prmation: Certification Date:07/28/2023 Term: 36 Months Expiration Date: 07/28/2026
tl:
This cylinder was certified according to the 2012 EPA Traceability Protocol, Document #EPA-6001R-12/531, using Procedure G1. Uncertainty above is expressed as absolute expanded
uncertainty at a level of confidence of approximately 95% with a coverage factor k = 2. Do Not Use this Standard if Pressure Is less than 100 PSIG. ·
Analvtical Data: (R=Reference Standard, Z=Zero Gas, C=Gas Candidate)
1 . Component: Carbon monoxide
Requested'Concentration; 47.5 ppm
Certified Concentration: 47.5 ppm
Instrument Used: Horiba VIA-51 O S/N 43627990042
Analytical Method; NDIR
Last Multipoint Calibration: 06/27/2023
Reference Standard: Type I Cylinder#: GMIS / DT0034303
Concentration/ Uncertainty: 50.4 ppm ±0.2 ppm
Expiration Date: 12/21/2030
Traceable to: SRM #/Sample#/ Cylinder#: SRM 1678c/ 4-L-41 / FF18402
SRM Concentration I Uncerta_inty: 49.136 ppm/ ±0.065 ppm
SRM Expiration Date; 04/22/2029
First Analysis Data: Date 07/20/2023 Second Analysis Data: .. . . . . . Date .
.· ... _· z· .... JL----·R: . soA·• • . ..::'.··"-.i>.--,""!7.4..-..:.-earrc:-·4-7:4'----·-·' ~-~,.-----· ·y, · o · R: · o · · c;-···•~· .. ·•"7:~~-;;·· o·
R: 50.5 Z: 0 C: 47.6 Cone: 47.6 R: 0 Z: 0 C: O Cone: 0
Z: 0 C: 47.5 R: 50.3 Cone: 47.5 Z: O C: O R: O Cone: O
UOM: ppm Mean Test Assay: 4 7 .5 ppm :
2. Component: Nitric oxide
Requested Concentration: 47.5 ppm
Certified Concentration: 47.1 ppm
UOM: ppm Mean Test Assay:
Reference Standard: Type I Cylinder#: GMIS / ND8756
Concentration/ Uncertainty: 47.4 ppm ±0.2 ppm
Expiration Date: 12/02/2025
ppm
Instrument Used: Thermo Electron 42i-LS S/N 1030645077 Traceable to: SRM #/Sample# I Cylinder#: PRM / C1765710.01 / APEX1324323
Analytical Method: Chemiluminescence SRM Concentration/ Uncertainty: 50.04 ppm _I ±0.20 ppm
Last Multipoint Calibration: 06/28/?023 SRM Expiration Date: 12/09/2022
First Analysis Data: Date 07/20/2023 Second Analysis Data: Date 07/28/2023
Z: 0 R: 47.4 C: 47 Cone: 47 Z: 0 R: 47.4 C: 47 Cone: 47
R: 47.4 Z: 0 C: 47.1 Cone: 47.1 R: 47.4 Z: 0 C: 46.9 Cone: 46.9
Z: 0 C: . 47.1 R: 47.3 Cone: 47.1 Z: 0 C: 47.1 R: 47.3 Cone: 47.1
UOM: ppm Mean Test Assay: 47.1 ppm UOM: ppm Mean Test Assay: 47 ppm
Analyzed By Henry Koung Certified By
Information contained herein has been prepared at your request by qualified experts within Linde Gas & Equipment Inc. While we believe that the information is accurate within the limits of the
analytical methods employed and Is complete to the extent of the specific analyses performed, we make no warranty or representation as to the suitability of the use-of the information for any purpose.
The information is offered with the understanding that any_use,pf the information is at the sole discretion and risk of the user. In no evon!;shall the liability of Linde Gas & Equipment Inc. , arising out
of the use of the information contained herein exceed'the fee established for providing such information. 'w • Page 1 of 1
Making our wotld
more productive
DocNumber: 584502
Certificate lssuanc~ Date: 11/22/2024
Linde Order ~umber: 72970221
Linde Gas & Equipment Inc.
5700 S. Alameda Street
Los Angeles CA 90058
Tel: [phone]
Fax: [phone]
PGVP ID: F22024
Fifi Date: 10/29/2024
Lot Number: 70086430307
Customer & Order Information
LGEPKG PROVO UT HS
1211 S INDUSTRIAL PKWY
PROVO UT 84606-6136
Part Number: NI CD4.75O1E-AS
Customer PO Number: 80985544
Cylinder Style & Outlet: AS CGA 660
I Cylinder Pressure and Volume: 2000 psig 145 ft3
Certified Co~centration
Expiration Date: 11/22/2032
:!
NIST Traceable
Cylinder Number: DT0009034 Expanded Uncertainty
4.73 % Carbon dioxide ±0.04%
4.83 % Oxygen :t 0.04 %
Balance Nitrogen I
Certification Information: Certification Date: 11/22/2024 Term: 96 Months Expiration Date: 11/22/2032
~-
This cylinder was certified according to the 2012 EPA Traceability Protocol, Document #EPA-600/R-12/531, using Procedure G1. Uncertainty above is expressed as absolute expanded
uncertainty at a level of confidence of approximately 95% with a coverage factor k = 2. Do Not Use this Standard if Pressure is less than 100 PSIG.
Ana(vtical Data: (R=Reference Standard, Z=Zero Gas, C=Gas Candidate)
1 . Component: Carbon dioxide
Requested Concentration: 4.75 %
Certified Concentration: 4,73 %
Reference Standard: Type I Cylinder#: NTRM / DT0030197
Concentration/ Uncertainty: 7.011 % ±0.058 %
Expiration Date: 01127/2027
Instrument Used: Horiba VIA-510 S/N 20C194WK
NDIR
Traceable to: SRM #/Sample#/ Cylinder#: NTRM#DT0030296 / 190702 / DT0030296
Analytical Method: SRM Concentration/ Uncertainty: 7.0111 ±0.058
Last Multipoint Calibration: 10/28/2024 SRM Expiration Date: 01/2712027
First Analysis Data: Date 11122/2024 Second Analysis Data: Date
~·---=---~··. >--=·,....,. J: ___ o. __ R: .Z.O.:L---C.~-4,7.3 ___ Conc:__4.J'.3, _____ \-, ~~ ----~·=,R,="•0,-=-,~~ C•· ·.o,::..~onc:..~Q___:_ _
R: 7.01 Z: 0 C: 4.73 Cone: 4.73 )
Z: 0 C: 4.72 R: 7.01 Cone: 4.72
R: 0 Z: 0 C: 0 Cone: 0
Z: 0 C: O R: 0 Cone: O
UOM: % Mean Test Assay: 4.73 %
2. Component: Oxygen
Requested Concentration: 4.75 %
Certified Concentration: 4.83 %
Instrument Used: Siemens Oxymat 6E S/N 7MB20211AA000CA 1
Analytical Method: Paramagnetic
Last Multipoint Calibration: 10/31/2024
First Analysis Data:
Z: 0 R: 5.008
R: 5.009 Z: 0
Z: 0 C: 4.833
C: 4.832
C: 4.832
R: 5.01
Date 11/22/2024
Cone: 4.83
Cone: 4.83
Cone: 4.83
UOM: % Mean Test Assay: 4.83 %
Analyzed By Miriam Bahena
UOM: % Mean Test Assay:
Reference Standard: Type I Cylinder#: GMIS / ND65909
Concentration/ Uncertainty: 5.007 % ±0.040 %
Expiration Date: 07/31/2032
Traceable to: SRM #/Sample#/ Cylinder#: NTRM / 170701 / CC92555
SRM Concentration/ Uncertainty: 9.875% I ±0.04%
SRM Expiration Date: 07/21/2029
Second Analysis Data:
Z: 0 R: 0 C:
R: 0 Z: 0 C:
Z: 0 C: 0 R:
Date
Cone: o
Cone: 0
Cone: 0
UOM: % Mean Test Assay:
Certified By Ilk& Nelson Ma
%
%
Information contained herein has been prepared at your request by qualified experts within Linde Gas & Equipment Inc. While we believe that the information is accurate within the limits of the
analytical methods employed and is complete to the extent of the specific analyses performed, we make no warranty or representation as to the suitabilily of the use of the information for any purpose.
The information is offered with the understanding that any use of the information is at the sole discretion and risk of the user. In no event shall the liability of Linde Gas & Equipment Inc. , arising out
of the use of the information contained herein exceed the fee established for providing such information. 1 Of 1
Making our world
moie productive
DocNumber: 584390 II .
Certificate Issuance Date: 11/20/2024
Linde Order Number: 72970221
'
Linde Gas & Equipment Inc.
5700 S. Alameda Street
Los Angeles CA 90058
Tel: [phone]
Fax: [phone]
PGVP ID: F22024
Fill Date: 10/30/2024
Lot Number: 70086430404
Customer & Order Information
LGEPKG PROVO UT HS
1211 S INDUSTRIAL PKWY
PROVO UT 84606-6136
Part Number: NI CD9,75O1E-AS
Customer PO Number: 80985544
Cylinder Style & Outlet: AS CGA 590
Cylinder Pressure and Volume: 2000 psig 148 ft3
Certified Concentration ProSpec EZ Cert
Expiration Date:
Cylinder Number:
9.66 %
9.72 %
Balance
11/20/2032
CC725990
Carbon dioxide
Oxygen
Nitrogen
NIST Traceable
Expanded Uncertainty
± 0.04%
±0.03 %
Certification 1n[ormation: Certification Date: 11/20/20~4 Term: 96 Months Expiration Date: 11/20/2032
This cylinder was certified according to the 2012 EPA Traceability Protocol, Document #EPA-600/R-12/531, using Procedure G1. Uncertainty above is expressed as absolute expanded
uncertainty at a level of confidence of approximately 95% with a coverage factor k = 2. Do ,Not Use this Standard if Pressure is less than 100 PSIG,
CO2 responses have been corrected for Oxygen IR Broadening effect. 02 responses have been corrected for CO2 Interference.
Analytical Data: {R=Reference Standard, Z=Zero Gas, C=Gas Candidate)
1 . Component: Carbon dioxide
Requestea Concentration: 9.75 %
Certified Concentration: 9.66 %
Reference Standard: Type I Cylinder#: GMIS / ND54512
Concentration / Uncertainty: 13.92 % ±0.06 %
Expiration Date: 06/06/2031
Instrument Used: _Horiba VIA-510 S/N 20C194WK
NDIR
Traceable to: SRM #/Sample# / Cylinder#: RGM / 109433807 / CC28033
Analytical Method: SRM Concentration/ Uncertainty: 19.63% I ±0,07%
Last Multipoint Calibration: 10/28/2024 SRM Expiration Date: 05/11/2025
First Analysis Data: Date 11/20/2024 Second Analysis Data: Date
Z: 0 R: 13.92 C: 9.66 Cone: 9.66 Z: o R: o C: o Cone: 0
R: 13.92 Z: 0 C: _ 9.~: ~.66 ~" .----------R.-----0--------"'"e~----~o _ . =-·.-c:-~----cori-C:-~ q··~-.. · <·-...c · ~-' · ,___...,.__ .
--'"".,---:::: .-· -.-,-.~---f-Z:· -er,--~1;;~~92 Cone: 9.66 Z: o C: o R: 0 Cone: 0
UOM: % Mean Test Assay: 9.66 %
2. Component: Oxygen
Requested Concentration: 9. 75 %
Certified Concentration: 9.72 %
Instrument Used: Siemens Oxymat 6E S/N 7MB20211AA000CA1
Analytical Method: Paramagnetic
Last Multipoint Calibration: 10/31/2024
First Analysis Data: Date 11/20/2024
Z: 0 R: 15,08 C: 9.74 Cone: 9.72
R: 15,12 Z: 0 C: 9.74 Cone: 9.72
Z: 0 C: 9.74 R: 15.11 Cone: 9.72
UOM: % Mean Test Assay: 9.72 %
~~ &# Analyzed By Miriam Bahena
UOM: % Mean Test Assay:
Reference Standard; Type/ Cylinder#: GMIS / CC506236
Concentration/ Uncertainty: 15.08 % ±0,03 %
Expiration Date: 10/10/2031
Traceable to: SRM #/Sample#/ Cylinder#: 2659a /71-E-19 / FF22331
SRM Concentration I Uncertainty: 20.863% / ±0,021%
SRM Expiration Date: 02/27/2026
Second Analysis Data: Date
Z: 0 R: 0 C: 0 Cone:
R: 0 Z: 0 C: 0 Cone:
Z: 0 C: 0 R: 0 Cone:
UOM: % M_ean Test Assay:
Certified By /lf#mll4
Nelson Ma
%
0
0
0
%
Information contained herein has been prepared at your request by qualified experts within Linde Gas & Equipment Inc. While we believe that the information is accurate within the limits of the
analytical methods employed and is complete to the extent of the specific analyses performed, we make no warranty or representation as to the suitability of the use of the information for any purpose.,
The information is offered with the understanding that any use of the information is at the sole discretion and risk of the user. In no event shall the liability of Linde Gas & Equipment Inc. , arising out
of the use of the information contained herein exceed the fee established for providing such information. i Of 1.
..
Making our world
more productive
DocNumber: 555077
Certificate Issuance Date: 08/11/2023 ,
Linde Ord~r Number: 72533908
Linde Gas & Equipment Inc.
5700 S. Alameda Street
Los Angeles CA 90058
Tel: [phone]
Fax: [phone]
PGVP ID: F22023
Fill Date: 08/07/2023
Lot Number: 70086321907
Customer & Order Information
LGEPKG SALT LAKE CITY UT H 6880 S 2300 E . Pah Number: NI CD20.5O1 E-AS
Customer P~ Number: 80543739
Cylinder Style & Outlet: AS CGA 590
SALT LAKE CIT'( UT84121-3183 Cylinder Pressure and Volume: 2000 psig 158 ft3
E~piration Date:
Cylfnder Number:
20.41 %
20.73 %
Balance
Certified clncentration
08/11/2031
CC145183
Carbon dioxide
Oxygen
Nitrogen
NIST Traceable
Expanded Uncertainty
±0.06%
±0.04%
Certijicatio,n Information: Certification Date:08/11/202,i Term: 96 Months Expiration Date: 08/11/2031
This cylinder w~ certified according to the 2012 EPA Trac~abHity Protocol, Document #E~t600/R-12/531, using Procedure G1. Uncertainty above is expressed as absolute expanded
uncertainty at a level of confidence of approximatel;· 95% with a coverage factor k = 2. Do Not Use this Standard If Pressure Is less than 100 PSIG. ·,
CO2 responses have been corrected for Oxygen IR Broadenl;i,:J affec~. 02 responses have ~Ben correclf!d for CO2 interference.
Anafvtical Data: (R=Reference Standard, Z=Zero Gas, C=Gas Candidate)
1. Component: Carbon dioxide
Requ~sted Concentration: 20.5 %
Certified Concentration: 20.41 %
Reference Standard: Type/ Cylinder#: GMIS / CC305911
Concentration/ Uncertainty: 26.96 % ±0.05 %
Expiralion Date: 03/29/2031
Instrument Used: Horiba VIA-510 S/N 20C194WK Traceable to: SRM #/Sample# /Cylinder#: RGM#CC193512 / N/A / CC193512
Analytical Method: NDIR
Last Multipoint Calibration: 07/28/2023
First Analysis Data:
Z: 0 R: 26.96 C:
Date
20.42 Cone:
08/11/2023
20.42 '" 2e.se ·~--z~,-~---~-,,.~~---~"'2"'0 . ..,.4•1-~,,.__,_. 0 C: 20.41 -~·"-Cone:
Z: 0 C: 20.41 20.41 R: 26.96 Cone:
UOM: % 20.41 % Mean Test Assay:
2. Component: Oxygen
Requested Concentration: 20.5 %
Certified Concentration: 20.73 %
Instrument Used: Siemens Oxymat 6E S/N 7MB20211AA000CA 1
Analytical Melhod: Paramagnetic
Last Multipoint Calibration: 07/28/2023
First Analysis Data:
Z: 0 R: 24.96
Z: 0
C: 20.76
C: 20.75
C: 20.73
R: 24.98
Date 08/11/2023
Cone: 20.74
Cone: 20.72
Cone: 20.75
R: 24.99
Z: 0
UOM: % Mean Test Assay: 20.73 %
Analyzed By
SRM Concentralion / Uncertainty: 26.99% / ±0.05%
SRM Expiration Date: 05/15/2023
Second Analysis Data: Date
_z, __ o R: 0. C: O Cone: O .~z~,-~o ..... --c;~---Col'I~: ·Q~ R: O
Z: 0 C: O R: O Cone: o
UOM: % Mean Test Assay:
Reference Standard: Type/ Cylinder#: GMIS / DT0025134
Concentration / Uncertainty: 24.96 % ±0.04 %
Expiration Date: 12/14/2026
Traceable to: SRM #/ Sample#/ Cylinder#: SRM 2659a /71-E-19/ FF22331
SRM Concentration/ Uncertainty: 20.863% /±0.021%
SRM Expiration Date: 02/27/2026
Second Analysis Data: Date
Z: 0 R: 0 C: 0 Cone: 0
R: 0 Z: 0 C: 0 Cone: 0
Z: 0 C: 0 R: 0 Cone: 0
UOM: % Mean Test Assay:
CertifleffBy
%
%
Information contained herein has been prepared at your request by qualified experts within Linde Gas & Equipment Inc. While we believe that the information is accurate within the limits of the
analytical methods employed and is complete to the extent of the specific analyses performed, we make no warranty or representation as to the suitability of the use of the informatiori for any purpose.
The information is offered with the understanding that any use of the information is at the sole discretion and risk of the user. In no event shall the liability of Linde Gas & Equipment Inc. , arising out
of the use of the Information contained herein exceed the fee established for providing such information. Page 1 of 1