DAQ-2025-002630

1

DAQC-518-25
Site ID 10119 (B5)

MEMORANDUM

TO: CEM FILE – CHEVRON PRODUCTS COMPANY

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Rob Leishman, Environmental Scientist

DATE: May 28, 2025

SUBJECT: Source: Fluidized Catalytic Converting Unit (FCCU), Sulfur Reduction
Unit (SRU1 and SRU2), Boiler 7, Flare #3, and Refinery Fuel
Gas
Contact: Tony Pollock – 801-539-7162
Location: 685 South Chevron Way, North Salt Lake, Davis County, UT
Test Contractor: Alliance Technical Group
FRS ID#: UT0000004901100003
Permit/AO#: AO DAQE-AN101190107-24 dated December 3, 2024
40CFR60 Subparts J/Ja
40CFR63 Subpart UUU
Subject: Review of RA/PST Protocol received May 12, 2025

On May 12, 2025, Utah Division of Air Quality (DAQ) received a protocol for a RA/PST (relative
accuracy/performance specification test) of the Chevron Products Company SRU #1 and #2, FCCU,
Boiler #7, Refinery Fuel Gas, and Flare #3 in North Salt Lake, Utah. Testing will be performed on August
11-26, 2025, to determine the relative accuracy of the H2S, SO2, CO2, CO, NOx, and O2 monitoring
systems.

PROTOCOL CONDITIONS:

1. RM 1 used to determine sample velocity traverses: OK
2. RM 2 used to determine stack gas velocity and volumetric flow rate: OK
3. RM 3A used to determine dry molecular weight of the gas stream: OK
4. RM 4 used to determine moisture content: OK
5. RM 6C used to determine SO2 emissions: OK
6. RM 7E used to determine NOX concentrations of emissions: OK
7. RM 10 used to determine CO concentrations of emissions: OK
8. RM15 used to determine H2S content of fuel gas in stationary sources by gas
chromatography: OK

1 8 2
2

9. RM 19 used to determine volumetric flow: OK
10. RM 205 205 used to validate gas dilution systems for field instrument calibration: OK

DEVIATIONS: No deviations were noted.

CONCLUSION: The protocol appears to be acceptable.

RECOMMENDATION: Send attached protocol review and test date confirmation notice.
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Continuous Emissions Monitoring
System Relative Accuracy Test
Protocol
Chevron Products Company
Salt Lake City Refinery
685 South Chevron Way
North Salt Lake, utah 84054
Sources to be Tested: Multiple Sources
Proposed Test Dates: August 11, 13 - 15, 25 &.
Project No. AST-2025 -207 I
Prepared B
Alliance Techni
3683 W 22
West Val
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I Site Specific Test Plan
Test Proqram Surnmary
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Resulatorv Information
Permit No. UDAQ DAQE-AN10ll90l06-24
Regulatory Citations 40 CFR 60, Appendix B, Performance Specifications 2, 3, 414A,6 all.d7
40 CFR 60 |a,40 CFR 63, UUU
NSPS Db
Source Information
Source Nome
SRU and Tail Gas Incinerator #l
SRU and Tail Gas Incinerator #2
Catalyst Regenerator / Fluidized Catalytic
Cracking Unit (FCCU) and Catalyst
Regenerator
F-l 1007
Alkylation Flare
Source ID
SRUI
SRU2
FCC
Boiler 7
Flare 3
Target Parameters
VFR, Oz, SOz
VFR, Oz, SOz
Oz,COz, SOz, NOx, CO
oz, Nox
HzS
HzSRFG / Refinery Fuel Gas Mix Point Refinery Fuel Gas
Contact Information
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Test Location Test Company
Chevron Products Company Alliance Technical Group, LLC
Salt Lake City Refinery 3683 W 2270 S, Suite E
685 South Chevron Way West Valley City, UT 84120
North Salt Lake, Utah 84054
Project Manager
Facility Contact Charles Horton
Tony Pollock [e-mail]
[e-mail] [phone]
[phone]
Field Team Leader
Alan Jensen
alan [e-mail]
[phone]
(subject to change)
QA/QC Manager
Kathleen Shonk
katie.shonk@all iancetg.com
(8t2) 4s2-478s
Test Plan/Report Coordinator
Delaine Spangler
[e-mail]
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I Site Specifc Test Plan
Table of Contents
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TABLE OF CONTENTS
2.0 Summary of Test Program ............2-l
2.2 Process/Control System Parameters to be Monitored and Recorded ................. ...................2-l
3.1 U.S. EPA Reference Test Methods I and 2 - Sampling/Traverse Points and Volumetric Flow Rate ........ 3-l
3.2 U.S. EPA Reference Test Method 3A - Oxygen/Carbon Dioxide......... .........3-2
3.3 U.S. EPA Reference Test Method 4 - Moisture Content......... .......................3-2
3.4 U.S. EPA Reference Test Method 6C - Sulfur Dioxide......... ......................... 3-2
3.5 U.S. EPA Reference Test Method 7E - Nitrogen Oxides .........3-2
3.6 U.S. EPA Reference Test Method 10 - Carbon Monoxide..... ........................3-2
3.7 U.S. EPA Reference Test Method 15 - Hydrogen Su1fide....... .......................3-3
3.8 U.S. EPA Reference Test Method 19 - Mass Emission Factors ..................... 3-3
3.9 U.S. EPA Reference Test Method 205 - Gas Dilution System Certification. ....................... 3-3
3.10 Quality Assurance/Quality Control - U.S. EPA Reference Test Methods 3,{, 6C, 7E and l0 .............. 3-4
LIST OF TABLES
Table 2-l: Program Outline and Tentative Test Schedule ......................2-2
Table 2-2: Relative Accuracy Requirements and Limits.... ....................2-3
LIST OF APPENDICES
t Appendix A Method I Field Data Sheet
Appendix B Example Field Data Sheets
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Site Specrfic Test Plan
Introduction
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1.0 Introduction
Alliance Technical Group, LLC (Alliance) was retained by Chevron Products Company (Chevron) to conduct
performance specification (PS) testing at the North Salt Lake, Utah facility. Portions of the facility are subject to
provisions of the 40 CFR 60, Appendix B, PS 2, 3,414A,6 and7,40 CFR 60 Ja, 40 CFR 63, UUU, the Utatt
Department of Environmental Quality, Division of Air Quality (UDAQ) Permit No. UDAQ DAQE-ANl0l190106-
24, and NSPS Db. Testing will be conducted as outlined in Table l-l below.
This Continuous Emissions Monitoring System Relative Accuracy Test Protocol has been prepared to address the
notification and testing requirements of the UDAQ permit.
Table 1-1: Test Matrix
l.l Facility Description
Chevron Salt Lake Refinery is a petroleum refinery with a nominal capacity of approximately 55,000 barrels per day
of crude oil. The source consists of one FCC unit, a delayed coking unit, a catalytic reforming unit, hydrotreating
units and two sulfur recovery units. The source also has assorted heaters, boilers, cooling towers, storage tanks,
flares, and similar fugitive emissions. The refinery operates with a flare gas recovery system on two of its three
hydrocarbon flares.
1.2 CEMS Descriptions
SRU/
U SO2 Flow RateAmetek Ametek Optical Scientific9900 9900 0Fs-2000
zw-9900-sr332-l zw-9900-s1332-l 0502166E
0-l0o/o 0-500ppm 0-66FPS
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Make:
Model:
Serial No.:
Range:
SRU and Tail Gas Incinerator #l (SRUl)Volumetric Flow Rate (VFR), Orygen (Oz), Sulfur
Dioxide (SOz)
SRU and Tail Gas Incinerator #2 (SRU2)
Catalyst Regenerator / Fluidized Catalytic Cracking Unit
(FCCU) and Catalyst Regenerator (FCC)
Oz, Carbon Dioxide (COz), SOz, Nitrogen Oxides
(NOx), Carbon Monoxide (CO)
F-l1007 (Boiler 7)
Hydrogen Sulfide (H2S)Alkylation Flare (Flare 3)
RFG / Refinery Fuel Gas Mix Point (Refinery Fuel Gas)
AST-202s-2071 -00 I Chevron - North Salt Lake, UT
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I Site Specific Test Plan
Introduction
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SRU2
A SA Flow Rate
Make: Ametek Ametek Thermox
Model: 9900 9900 OFS - 2000
SerialNo.: AV-9000WM-10235-lA AV-9000WM-10235-lA 9080423
Range: 0-25o/o 0-500ppm 0-66FPS
FCC
92 eA SA Nox Co
Make: Siemens Siemens Siemens western
Research Siemens
Model: Ultramat/Oxymat UltramaVOxymat Ultramat 922 NOx Ultramat
SerialNo.: J7-447 J7-447 J6-783 ZW-9900-1334-l J6-783
Range: 0-10% 0-25o/o 0-200ppm 0-200ppm 0-1000ppm
Boiler 7
a NOx
Make: Ametek Ametek
Model: 9900 9900
SerialNo.: 2E9900-10941-l 2E9900-10941-l
Range: 0-2lo/o 0-500ppm
Flare 3
Hz'S
Make: Siemens
Model: Maximum II
Serial No.: OK830068232740010
Range: 0-300ppm
Refinery Fuel Gas
Hd
Make: Siemens
Model: Maxim II
SerialNo.: 30019536380010
Range: 0-300ppm
1.3 Project Team
Personnel planned to be involved in this project are identified in the following table.
Table 1-2: Project Team
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Chevron Personnel Tony Pollock
Regulatory Agency UDAQ
Alliance Personnel Alan Jensen
other field personnel assigned at time oftesting event
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AI Site Specrf;c Test Plan
Introduction
1.4 Safety Requirements
Testing personnel will undergo site-specific safety training for all applicable areas upon arrival at the site. Alliance
personnel will have current OSHA or MSHA safety training and be equipped with hard hats, safety glasses with side
shields, steel-toed safety shoes, hearing protection, fire resistant clothing, and fall protection (including shock
corded lanyards and full-body hamesses). Alliance personnel will conduct themselves in a manner consistent with
Client and Alliance's safety policies. Alliance will use 4 personal gas monitors to monitor HzS, SOz, Oz, and CO
levels while onsite.
A Job Safety Analysis (JSA) will be completed daily by the Alliance Field Team Leader.
Fla
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I Site Specrfic Test Plan
Sumnnry ofTest Programs
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2.0 Summary of Test Program
To satisfu the requirements of UDAQ permit AN-101190107-24,40 CFR 60, Appendix B, PS 2,3,414A,6 and7,
40 CFR 60 Ja, and 40 CFR 63, UUU, Chevron Salt Lake Refinery will conduct a PS test program to determine the
compliance status of the SRUI, SRU2, FCC, Boiler 7, Flare 3, and Refinery Fuel Gas CEMS.
2.1 General Description
All testing will be performed in accordance with specifications stipulated in U.S. EPA Reference Test Methods l, 2,
3A,4,6C,78, 10, 15, and 19. Table 2-l presents an outline and tentative schedule for the emissions testing
program. The following is a summary of the test objectives.
Testing will be performed to demonstrate compliance with UDAQ permit AN-101190107-24 and 40 CFR
60, Appendix B, PS 2, 3,414A,6 and 7,40 CFR 60 Ja, and 40 CFR 63, UUU.
Emissions testing will be conducted on the exhaust of SRUI, SRU2, FCC, Boiler 7, Flare 3, and Refinery
Fuel Gas.
Performance testing will be conducted at least 50% of the operating load.
Each of the ten (10) test runs will be 2l minutes in duration for the 02, CO2, NOx, SO2, and CO testing.
Each of the ten (10) test runs will be 30 minutes in duration for the H2S testing.
Each of the three to four (3-4) test runs will be 60 minutes in duration per source for the moisture content
testing.
2.2 Process/Control System Parameters to be Monitored and Recorded
Plant personnel will collect operational and parametric data at least once every 15 minutes during the testing. The
following list identifies the measurements, observations and records that will be collected during the testing
program:
CEMS/CERMS Data
Product Loaded
2.3 Proposed Test Schedule
Table 2- I presents an outline and tentative schedule for the emissions testing program.
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,,"Aliatpe Sire Specrfic Test Plan
Summary ofTest Programs
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Table 2-l: Program Outline and Tentative Test Schedule
Testing Locetion Peremcter US EPA Method No ofRuns Run Durrtion Est. Onsite
Tlme
August 11,2025
Equipment Setup & Pretest QA/QC Checks
l0 hr
FCC
VFR t&2
l0 2l min
O:/CO:3A
SO:6C
NOx 7E
CO l0
BWS 4 J 60 min
August 12.2025
Testing conducted on other sources
August 13,2025
SRUI
VFR t&2
l0 2l min
l0 hr
O:/CO:3A
SO:6C
BWS 4 3-4 60 min
August 14,?025
SRU2
VFR t&2
l0 2l min
l0 hr
O:/CO:3A
SO:6C
BWS 4 3-4 60 min
August 15,2025
Boiler 7
O:/CO:3A
t0 2l min l0 hrNOx7E
EF l9
August 16-24,2025
Testing conducted on other sources
August 25,2025
Flare 3 H:S l5 l0 30 min l0 hr
August 26.2025
Refinery Fuel Gas H:S l5 l0 30 min l0 hr
August 26.2025
Contingency Day (if needed). Demobilization
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Allalpe Srte Spectfic Test Plan
SummaryofTest Programs
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2.4 Emission Limits
Emission limits for each pollutant are below
Table2-2t Relative Accuracy Requirements and Limits
Source CEMS Required Relative
Accrrrlcv ^A,pplicable Stenderd /
Limit Citation
SRUI
VFR s20 % (RM)60, Appendix B, PS 6
o:<20 % (RM) or + I 7o O:
(ave. diff.)60, Appendix B, PS 3
SOz
<20% ofRM or
Sl0 % of AS
250 ppmvd @ 0'/,O2,
0.242 tpd 60, Appendix B, PS 2
SRU2
VFR s20 % (RM)60, Appendix B, PS 6
o:<20%(RM)or+lo/oOz
(ave. diff.)60, Appendix B, PS 3
SO:S20% ofRM or
<10 % of AS
250 ppmvd @ 0o/,O2,
0.268 tDd 60, Appendix B, PS 2
FCC
o:<20 % (RM) or + I o/o Oz
(avs. diff. )60, Appendix B, PS 3
CO:S20 % (RM) or + I 7o CO:
(ave. diff.)60, Appendix B, PS 3
SO:<20% ofRM or
110 % of AS 50 ppmvd @0%oO2 60, Appendix B, PS 2
NOx <20% ofRM or
StO % of AS 80 ppmvd @ 0%oO2 60, Appendix B, PS 2
CO
<207o ofRM or
<10 o/o of AS or
55 ppm ofdifference plus
the confi dence coeffi cient
500 ppmvd@ 0% 02 60, Appendix B, PS 44
Boiler 7
o:S20 % (RM) or t I o/o Oz
(ave. diff.)60, Appendix B, PS 3
NOx <20 % (RM) or 110 % (AS)0.201b/MMBtu 60, Appendix B, PS 2
Flare 3 H:S S20 % (RM) or 110 % (AS)162 ppmv 60, Appendix B, PS 7
40 CFR 60 Ja
Refinery Fuel
Gas H:S <20 % (RM) or 110 % (AS)162 ppmv 60, Appendix B, PS 7
40 CFR 60 Ja
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AI Site Specific Test Plan
Summary ofTest Programs
2.5 Test Report
The final test report must be submitted within 60 days of the completion of the performance test and will include the
following information. In addition to the final test report, the test results must be entered into the U.S. EPA
Electronic Reporting Tool (ERT) for submittal via CEDRI for units for SRUI, SRU2 for SOz and Oz and FCC for
co.
o Introduction - Brief discussion of project scope of work and activities.
. Results and Discussion - A summary of test results and process/control system operational data with
comparison to regulatory requirements or vendor guarantees along with a description of process conditions
and/or testing deviations that may have affected the testing results.
o Methodolog - A description of the sampling and analytical methodologies.
. Sample Calculations - Example calculations for each target parameter.
. Field Data - Copies of actual handwritten or electronic field data sheets.
o Quality Control Data - Copies of all instrument calibration data and/or calibration gas certificates.
o Process Operating/Control System Data - Process operating and control system data (as provided by
Chevron) to support the test results.
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Testing llterlodology
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J.0 Testing Methodology
This section provides a description of the sampling and analytical procedures for each test method that will be
employed during the test program. AII equipment, procedures and quality assurance measures necessary for the
completion of the test program meet or exceed the specifications of each relevant test method. The emission testing
program will be conducted in accordance with the test methods listed in Table 3-1.
Table 3-l: Source Testing Methodology
All stack diameters, depths, widths, upstream and downstream disturbance distances and nipple lengths will be
measured on site with an EPA Method I verification measurement provided by the Field Team Leader. These
measurements will be included in the test report.
3.1 U.S. EPA Reference Test Methods I and 2 - Sampling/Traverse Points and Volumetric Flow Rate
The sampling location and number of traverse (sampling) points will be selected in accordance with U.S. EPA
Reference Test Method l. To determine the minimum number of traverse points, the upstream and downstream
distances will be equated into equivalent diameters and compared to Figure l-2 (measuring velocity alone) in U.S.
EPA Reference Test Method l.
Full velocity traverses will be conducted in accordance with U.S. EPA Reference Test Method 2 to determine the
average stack gas velocity pressure, static pressure and temperature. The velocity and static pressure measurement
system will consist of a pitot tube and inclined manometer. The stack gas temperature will be measured with a K-
type thermocouple and pyrometer.
Stack gas velocity pressure and temperature readings will be recorded during each test run. The data collected will
be utilized to calculate the volumetric flow rate in accordance with U.S. EPA Reference Test Method 2.
Stack gas velocity pressure and temperature readings will be recorded during each test run. The data collected will
be utilized to calculate the volumetric flow rate for comparison to the continuous emission rate monitoring system
(CERMS). The relative accuracy of the CERMS will be determined based on procedures found in 40 CFR 60,
Performance Specifi cation 6.
Prrrmetcr U.S. EPA Rcfcrcnce
Test Mcthods Notes/Remerks
Volumetric Flow Rate t &.2 Full Velocity Traverses
Oxygen/Carbon Dioxide 3A Instrumental Analvsis
Moisture Content 4 Gravimetric Analysis
Sulfur Dioxide 6C Instrumental Analysis
Nitrogen Oxides 7E Instrumental Analysis
Carbon Monoxide t0 Instrumental Analysis
Hydrogen Sulfide l5 Instrumental Analvsis
Mass Emission Factors l9 Fuel Factors/Heat Inputs
Gas Dilution System Certification 205
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Testing Methodology
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3.2 U.S. EPA Reference Test Method 3A - Oxygen/Carbon Dioxide
The oxygen (Oz) and carbon dioxide (CO2) testing will be conducted in accordance with U.S. EPA Reference Test
Method 3A,. Data will be collected online and reported in one-minute averages. The sampling system will consist
of a stainless steel probe, Teflon sample line(s), gas conditioning system and the identified gas analyzer. The gas
conditioning system will be a non-contact condenser used to remove moisture from the stack gas. If an unheated
Teflon sample line is used, then a portable non-contact condenser will be placed in the system directly after the
probe. Otherwise, a heated Teflon sample line will be used. The quality control measures are described in Section
3.10.
The relative accuracy of the Oz and COz CEMS will be determined based on procedures found in 40 CFR 60,
Appendix B, Performance Specification 3.
3.3 U.S. EPA Reference Test Method 4 - Moisture Content
The stack gas moisture content will be determined in accordance with U.S. EPA Reference Test Method 4. The gas
conditioning train will consist of a series of chilled impingers. Prior to testing, each impinger will be filled with a
known quantity of water or silica gel. Each impinger will be analyzed gravimetrically before and after each test run
on the same analytical balance to determine the amount of moisture condensed.
3.4 U.S. EPA Reference Test Method 6C - Sulfur Dioxide
The sulfur dioxide (SOz) testing will be conducted in accordance with U.S. EPA Reference Test Method 6C. Data
will be collected online and reported in one-minute averages. The sampling system will consist of a heated stainless
steel probe, Teflon sample line(s), gas conditioning system and the identified analyzer. The gas conditioning syst€m
will be a non-contact condenser used to remove moisture from the source gas. If an unheated Teflon sample line is
used, then a portable non-contact condenser will be placed in the system directly after the probe. Otherwise, a
heated Teflon sample line will be used. The quality control measures are described in Section 3.10.
The relative accuracy of the SOz CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specifi cation 2.
3.5 U.S. EPA Reference Test Method 7E - Nitrogen Oxides
The nitrogen oxides (NOx) testing will be conducted in accordance with U.S. EPA Reference Test Method 7E. Data
will be collected online and reported in one-minute averages. The sampling system will consist of a stainless steel
probe, Teflon sample line(s), gas conditioning system and the identified gas analyzer. The gas conditioning system
will be a non-contact condenser used to remove moisture from the stack gas. If an unheated Teflon sample line is
used, then a portable non-contact condenser will be placed in the system directly after the probe. Otherwise, a
heatedTeflonsamplelinewillbeused. ThequalitycontrolmeasuresaredescribedinSection3.l0.
The relative accuracy of the NOx CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specification 2.
3.6 U.S. EPA Reference Test Method l0 - Carbon Monoxide
The carbon monoxide (CO) testing will be conducted in accordance with U.S. EPA Reference Test Method 10.
Data will be collected online and reported in one-minute averages. The sampling system will consist of a stainless
steel probe, Teflon sample line(s), gas conditioning system, and the identified gas analyzer. The gas conditioning
system will be a non-contact condenser used to remove moisture from the gas. If an unheated Teflon sample line is
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Testing Methodologlt
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used, then a portable non-contact condenser will be placed in the system directly after the probe. Otherwise, a
heated Teflon sample line will be used. The quality control measures are described in Section 3.10.
The relative accuracy of the CO CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specification 4 or 4A.
3.7 U.S. EPA Reference Test Method l5 - Hydrogen Sulfide
The hydrogen sulfide testing will be conducted in accordance with U.S. EPA Reference Test Method 15. The
sampling system will consist of a heated Teflon probe, heated Teflon sample line, gas conditioning system, leak-free
pump, unheated Teflon sample line, to a Tedlar Bag. The gas conditioning system will consist of three (3) Teflon
impingers. The hrst two (2) impingers will contain 100 mL of cirate buffer (for SOz removal) and the last will be
empty. The bag samples will be analyzed with a gas ckomatograph (GC) equipped with a flame photometric detector
(FPD).
The sampling system will be leak checked before and after each integrated Tedlar bag sample will be collected. Each
test run will be 30 minutes in duration with nine to twelve (9-12) integrated bag samples comprising the run. The Tedlar
bag samples will be stored in a "minimum light" environment and analyzed as quickly as possible.
The GC/FPD will be calibrated for each sulfide compound (H2S, COS and CS) with a certified calibration gas diluted
with a dilution system validated in accordance with EPA Method 205 to three (3) or more concentration levels
spanning the linear range of the FPD. Calibration precision and calibration drift test values will be maintained in
accordance with EPA Method l5 requirements.
The relative accuracy of the HzS CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specifi cation 7.
3.8 U.S. EPA Reference Test Method 19 - Mass Emission Factors
The pollutant concentrations will be converted to mass emission factors (lb/MMBtu) using procedures outlined in
U.S. EPA Reference Test Method 19. The published dry Oz based fuel factor (F-Factor) of 8,710 dscf/MMBtu for
natural gas will be used in the calculations.
3.9 U.S. EPA Reference Test Method 205 - Gas Dilution System Certification
A calibration gas dilution system field check will be conducted in accordance with U.S. EPA Reference Method
205. An initial three (3) point calibration will be conducted, using individual Protocol I gases, on the analyzer used
to complete the dilution system field check. Multiple dilution rates and total gas flow rates will be utilized to force
the dilution system to perform two dilutions on each mass flow controller. The diluted calibration gases will be sent
directly to the analyzer, and the analyzer response will be recorded in an electronic field data sheet. A mid-level
supply gas, with a cylinder concentration within l0% of one of the gas divider settings described above, will be
introduced directly to the analyzer, and the analyzer response recorded in an electronic field data sheet. The
cylinder concentration and the analyzer response must agree within 2%. These steps will be repeated three (3)
times. The average analyzer response must agree within2o/o of the predicted gas concentration. No single injection
shall differ more than 2o/o from the average instrument response for that dilution.
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Testing Methodologlt
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3.10 Quality Assurance/Quality Control - U.S. EPA Reference Test Methods 3.{, 6C, 7E and l0
Cylinder calibration gases will meet EPA Protocol I (+l- 2%) standards. Copies of all calibration gas certificates
will be included in the Qualify Assurance/Quality Control Appendix of the report.
Low Level gas will be introduced directly to the analyzer. After adjusting the analyzer to the Low-Level gas
concentration and once the analyzer reading is stable, the analyzer value will be recorded. This process will be
repeated for the High-Level gas. For the Calibration Error Test, Low, Mid, and High-Level calibration gases will be
sequentially introduced directly to the analyzer. The Calibration Error for each gas must be within 2.0 percent of the
Calibration Span or 0.5 ppmvlo/o absolute difference.
High or Mid-Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe and the
time required for the analyzer reading to reach 95 percent or 0.5 ppm/% (whichever was less restrictive) of the gas
concentration will be recorded. The analyzer reading will be observed until it reaches a stable value, and this value
will be recorded. Next, Low-Level gas will be introduced at the probe and the time required for the analyzer reading
to decrease to a value within 5.0 percent or 0.5 ppm/% (whichever was less restrictive) will be recorded. If the Low-
Level gas is zero gas, the acceptable response must be 5.0 percent of the upscale gas concentration or 0.5 ppmlo/o
(whichever was less restrictive). The analyzer reading will be observed until it reaches a stable value, and this value
will be recorded. The measurement system response time and initial system bias will be determined from these data.
The System Bias for each gas must be within 5.0 percent of the Calibration Span or 0.5 ppmv/% absolute difference.
High or Mid-Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe. After the
analyzer response is stable, the value will be recorded. Next, Low-Level gas will be introduced at the probe, and the
analyzer value will be recorded once it reaches a stable response. The System Bias for each gas must be within 5.0
percent of the Calibration Span or 0.5 ppmv/7o absolute difference or the data is invalidated, and the Calibration
Error Test and System Bias must be repeated.
The Drift befween pre- and post-run System Bias must be within 3 percent of the Calibration Span or 0.5 ppmv/%
absolute difference or the Calibration Error Test and System Bias must be repeated.
To determine the number of sampling points, a gas stratification check will be conducted prior to initiating testing.
The pollutant concentrations will be measured at twelve traverse points (as described in Method 1) or three points
(16.7, 50.0 and 83.3 percent of the measurement line). Each traverse point will be sampled for a minimum of twice
the system response time.
If the pollutant concentration at each traverse point does not differ more than 5% or 0.5 ppml}.3Yo (whichever is less
restrictive) of the average pollutant concentration, then single point sampling will be conducted during the test runs.
If the pollutant concentration does not meet these specifications but differs less than l07o or 1.0 ppm/0.5% from the
average concentration, then three (3) point sampling will be conducted (stacks less than 7.8 feet in diameter - 16.7,
50.0 and 83.3 percent of the measurement line; stacks greater than 7.8 feet in diameter - 0.4, 1.0, and 2.0 meters
from the stack wall). If the pollutant concentration differs by more than l0% or 1.0 ppm/0.5% from the average
concentration, then sampling will be conducted at a minimum of twelve (12) traverse points. Copies of stratification
check data will be included in the Quality Assurance/Quality Control Appendix of the report.
An NOz - NO converter check will be performed on the analyzer prior to initiating testing or at the completion of
testing. An approximately 50 ppm nitrogen dioxide cylinder gas will be introduced directly to the NOx analyzer and
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the instrument response will be recorded in an electronic data sheet. The instrument response must be within +/- l0
percent of the cylinder concentration.
A Data Acquisition System with battery backup will be used to record the insfrument response in one (l) minute
averages. The data will be continuously stored as a *.CSV file in Excel format on the hard drive of a computer. At
the completion of testing, the data will also be saved to the Alliance server. All data will be reviewed by the Field
Team Leader before leaving the facility. Once arriving at Alliance's office, all written and electronic data will be
relinquished to the report coordinator and then a final review will be performed by the Project Manager.
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4.0 Quality Assurance Program
Alliance follows the procedures outlined in the Quality Assurance/Quality Control Management Plan to ensure the
continuous production of useful and valid data throughout the course of this test program. The QC checks and
procedures described in this section represent an integral part of the overall sampling and analytical scheme.
Adherence to prescribed procedures is quite often the most applicable QC check.
4.1 Equipment
Field test equipment is assigned a unique, permanent identification number. Prior to mobilizing for the test
program, equipment is inspected before being packed to detect equipment problems prior to arriving on site. This
minimizes lost time on the job site due to equipment failure. Occasional equipment failure in the field is
unavoidable despite the most rigorous inspection and maintenance procedures. Therefore, replacements for critical
equipment or components are brought to the job site. Equipment returning from the field is inspected before it is
returned to storage. During the course of these inspections, items are cleaned, repaired, reconditioned and
recalibrated where necessary.
Calibrations are conducted in a manner, and at a frequency, which meets or exceeds U.S. EPA specifications. The
calibration procedures outlined in the U.S. EPA Methods, and those recommended within the Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume III (EPA-600/R-941038c, September 1994) ue utilized.
When these methods are inapplicable, methods such as those prescribed by the American Society for Testing and
Materials (ASTM) or other nationally recognized agency may be used. Data obtained during calibrations is checked
for completeness and accuracy. Copies of calibration forms are included in the report.
The following sections elaborate on the calibration procedures followed by Alliance for these items of equipment.
o Dry Gas Meter and Orifice. A full meter calibration using critical orifices as the calibration standard is
conducted at least semi-annually, more frequently if required. The meter calibration procedure determines
the meter correction factor (Y) and the meter's orifice pressure differential (AH@). Alliance uses approved
Altemative Method 009 as a post-test calibration check to ensure that the correction factor has not changed
more than 57o since the last full meter calibration. This check is performed after each test series.
o Pitot Tubes and Manometers. Type-S pitot tubes that meet the geometric criteria required by U.S. EPA
Reference Test Method 2 are assigned a coefficient of 0.84 unless a specific coefficient has been
determined from a wind tunnel calibration. If a specific coefficient from a wind tunnel calibration has been
obtained that coefficient will be used in lieu of 0.84. Standard pitot tubes that meet the geometric criteria
required by U.S. EPA Reference Test Method 2 are assigned a coefficient of 0.99. Any pitot tubes not
meeting the appropriate geometric criteria are discarded and replaced. Manometers are verified to be level
and zeroed prior to each test run and do not require further calibration.
r Temoerature Measurins Devices. All thermocouple sensors mounted in Dry Gas Meter Consoles are
calibrated semi-annually with a NlST-traceable thermocouple calibrator (temperature simulator) and
verified during field use using a second NlST-traceable meter. NIST-traceable thermocouple calibrators
are calibrated annually by an outside laboratory.
Nozzles. Nozzles are measured three (3) times prior to initiating sampling with a caliper. The maximum
difference between any two (2) dimensions is 0.004 in.
Dieital Calipers. Calipers are calibrated annually by Alliance by using gage blocks that are calibrated
annually by an outside laboratory.
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Barometer. The barometric pressure is obtained from a nationally recognized agency or a calibrated
barometer. Calibrated barometers are checked prior to each field trip against a mercury barometer. The
barometer is acceptable if the values agree within + 2 percent absolute. Barometers not meeting this
requirement are adjusted or taken out of service.
Balances and Weights. Balances are calibrated annually by an outside laboratory. A functional check is
conducted on the balance each day it is used in the field using a calibration weight. Weights are re-certified
every two (2) years by an outside laboratory or internally. If conducted internally, they are weighed on a
NIST traceable balance. If the weight does not meet the expected criteria, they are replaced.
Other Equipment. A mass flow controller calibration is conducted on each Environics system annually
following the procedures in the Manufacturer's Operation manual. A methane/ethane penetration factor
check is conducted on the total hydrocarbon analyzers equipped with non-methane cutters every six (6)
months following the procedures in 40 CFR 60, Subpart JJJJ. Other equipment such as probes, umbilical
lines, cold boxes, etc. are routinely maintained and inspected to ensure that they are in good working order.
They are repaired or replaced as needed.
4.2 Field Sampling
Field sampling will be done in accordance with the Standard Operating Procedures (SOP) for the applicable test
method(s). General QC measures for the test program include:
. Cleaned glassware and sample train components will be sealed until assembly.
o Sample trains will be leak checked before and after each test run.
. Appropriate probe, filter and impinger temperatures will be maintained.
. The sampling port will be sealed to prevent air from leaking from the port.
. Dry gas meter, AP, AH, temperature and pump vacuum data will be recorded during each sample point.
o An isokinetic sampling rate of 90-l l0% will be maintained, as applicable.
o All raw data will be maintained in organized manner.
o All raw data will be reviewed on a daily basis for completeness and acceptability.
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'*';-:":: .,"t 3FC!'r :)
Method I Data
Sourca -
Prcjdl No. -t
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Drta
Diliu. A Dat lx.il.6:
Di.trmc B:
Diltmc B Dut lxfficn:
MinimM Nmbcr of Trrvane Pointt:
Actud N@lErof TrrvcBc Poinlt: _
Nur6.r ot R.rdinS! p.r Poirl: _M.s@r {Initid ud Dd.): _R.via.r (Inirid rnd D.t.):
10 I
tHbtur NumH b tdRfrt.edr Srd! d Ou&
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1r*lua&ytga
&tu.(&d arr-r
DEt Orianlrlioil _Dul DdlSn:
-
Dirr.mc frcm F r Wall to Oullida ol Pon: _in
Nlpple t ngth: _in
Dcpth of D6: m in
wklrh of DEr: - in
Cre$ Sctbnd Ar. ol lXd: - ftr
Equivrtnt DiG.r - itr
No. of T6t Poru: _Dillec A: fr
- (rur bc > o.5)
_fi
-----:-(m6l bc > 2)
-_____:_
LOCATION OF TUVERSE POlN'S
Nuilba oJ traws. NirB il o dtqn&,
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5
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130 J00 315 100 25.O 2tr 188 167
- r3l 625 J00 11.7 357 3ll 274
a15 700 583 J00 13ll 189
" - ,'., i:i-l # il iil
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15.0 13 6 12.
250 ll8 20
15 0 271 29
{50 t09 37
550 J00 rJ
6J0 J9t 51.
7J 0 6A2 62.
850 113 10
950 861 79.
-- 95J 87
9J
.P.rcent ofs,ack diailetcrfiom nskl. wall to lt@.ts. pont
./. ol
DirMGr
Di.lu.fmm
Poinr *all ou.id. of
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A= fl
B= ft.
Dcplh of DB = 0 m
Cr6s S.ctional AM Dowhstrcrm
DBtorb.nc.
upatraam
Dlrtu?b.rc.
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SO2 Summary
Locrtion:
Sourcc:
Projcci No.:
#N/Ato szs
n
Sd
CC
d
CC
RM
RA
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Confidcnce Coefficient, CC
whcre,
Relative Accurrcy, RA
p,q = !i-.E-lqgl'166
whcre,
= degrees offreedom value
= number of runs selected for calculating the RA: standard deviation ofdifference
= confidence coeffrcient
= average difference of Reference Method and CEMS
= confidence coefficient
= reference method, ppmvd @ 3 o/o 02
= relative accuracy, oh
Run
No.Dalc Timc Rcfercncc Method
SO2 Conccntrrtion
oomvd @.0 oh 02
CEMS
SO2 Conccntretion
oomvd@07o02
Avcrsgc
Diffcrcncc
oomvd @0 Yo02StrrtEnd
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Averag(
Standard Deviation (Sd
Applicable Source Standard (AS
Confidence Coefficient 1CC
Rclrtivc Accurrcy (RA
Performance Required - Mean Reference Method RA ! 20%
Performance Specifi cation Method PS2
NOx Summary
Locetion:
Sourcc:
Projcct No.:
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Confidcnce Cocfficicnt, CC
cc =lto=trsallVn I
wherc,
hszs #N/A = degrees offreedom value
n ----l- = number of runs selected for calculating the RA
Sd-= standard deviation of dift'erence
CC = confidence coefficient
Rcletive Accurrcy, RA
ldl+lcclRA = 7s;;Tr:xloo
wherc,
d = average difference of Reference Method and CEMS
CC
-=
confidence coefficient
RM
-=
reference method, ppmvd @ 3 % 02
RA = relative accwacy,o/o
Run
No.Drte Timc Rcfcrcnce Mcthod
NOx Conccntretion
oomvd(d.0 Yo02
CEMS
NOx Conccntrrtion
oomvd @0 oh 02
Avcrrge
Differcnce
oomvd @.0 o/o 02SterlEnd
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l0
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Averaq(
Standard Deviation (Sd
Aonlicable Source Standard (AS
Confidence Coefficient (CC
Rclativc Accuncv (RA
Performance Required - Mean Reference Method RAs20%
Performance Specr fi catron Method PS2
CO SummarylEe
;:,. ) i. {
Frar i..\AI
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Source:
Project No.:
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Confidcnce Coefficient, CC
cc : ltogt , sallr/n I
whcrc,
toe75 #N/A = degrees offieedom value
n 0 = number of runs selected for calculating the RA
sa-= standard deviation of difference
cc-= confidence coefficient
Rclativc Accuracy, RA
ldl+lcclRA = 'x 100AS or RM
whcre,
d _ = average difference of Reference Method and CEMS
CC _ = confidence coefficient
RM_= reference method, ppmvd @3%O2RA = relatrve accuracy, To
Altcrnetive Rclrtivc Accurrcy, RA
p,q : ldl+CC
whcre,
d = average drfference of Reference Method and CEMS
cc
-=
confidence coefficientM-= relative accuracy, ppm
Run
No.Drt.Timc Rtferencc Mcthod
CO Conccntrrtion
onmvd007"O2
CEMS
CO Concentretion
onmvd@07o02
Averege
Diffcrcncc
oomvd (d.0 oh 02StrrtEnd
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Averag(
Standard Deviation (Sd
Applicable Source Standard (AS
Confidence Coefficient (CC
Rclrtivc Accurrcy (RA
Performance Required - Mean Reference Methoc RA< t0%
Performance Soecifi cation Methoc PS 4A
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SOURCE TESTING H2S Summary
Location:
Source:
Project No.:I
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Confidence CoeIIicient, CC
CC:
where.
to.qrs
n
Sd
CC
mean difference
h szs
n
Sd
RM
RA
1" sa1n
#N/A : degrees offreedom
9 : number of runs selected for calculating the RA
standard deviation of di fference
confidence coefficient
Relative Accuracy, RA
lueor drfet encel-lf' , ta, Ipq= l{" l.t,
where.
'{s or lJ1
: average difference of Reference Method and CEMS
#N/A : degrees offreedom: number of runs selected for calculating the RA: standard deviation ofdifference: ret'erence method: relative accuracy
Run
No.Date Time Reference Method
H2S
oomvd
CEMS
H2S
oomvd
Average
Difference
oomvdStartEnd
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Average
Standard Deviation (Sd)
Applicable Source Standard (AS)t62
Confidence Coefficient (CC)
Relative Accuracy (RA)
Acceptability Criteria - Mean Reference Method <20Vo
Performance Specifi cation Method PS 7 (RM r5)
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VFR Summary
Sourcc: --
Projcct No.: --I
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Confidcnce Coefficient, CC
cc = ltolt , sallVn I
wherc,
tonrr1p!= degrees of freedom value
n-...1Q-: number of runs selected for calculating the RA
Sd_= standard deviation of difference
CC = confidence coeffrcient
Rcletivc Accurecy, RA
ldl+lcclfuq = --j---'----:x 100
where,
d-=averagedifIerenceofReferenceMethodandCEMS
CC _= confidence coefficient
W-_= reference method, dscfm
RA = relative accuracy,Yo
Run
No.Drtc Time Refcrence Method
Flow Rete
dscfm
CEMS
Flow Retc
dscfm
Avcrege
Difference
dscfmStNrtEnd
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0:00
0:00
0:00
0:00
0:00
0.00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
000
0:00
0:00
0:00
0:00
0:00
Averagr
Standard Deviation (Sd'
Confidence Coefficient (CC'
Rcletivc Accurecy (RAl
Acceptability Criteria - Mean Reference Method s20%
Performance Specifi cation Method PS6
AIErce Emissions Calculations
l23a367t9l0ttt2
Conccntdron Ppmvd Cn*
At6tpe
ll i lii r r\ ,,illlr. r
Run I Data
Location:
Source:
Project No.:
Date: -
o2
oh dry
Time
Unit
coz Soz
"h dry ppmvd
NOx CO HzS
ppmvd ppmvd ppmvw
Status Valid Valid Valid Valid Valid Valid
Uncorrected Run Average (Co6r)
Cal Gas Concentration (CrrrJ
Pretest System Zero Response
Posttest System Zero Response
Average Zero Response (Co)
Pretest System Cal Response
Posttest System Cal Response
Average Cal Response (Cs)
Corrected Run Average (Corr)
pulrffiirce QA Data
Location:
Source:
Project No.:
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Perameter o2 CO,SO,NOx CO HzS
Make
Model
i/N
0perating Renge
vlinder Number ID
LOW NA NA NA NA NA
MID
HIGH
Cvlinder Certified Values
LOW NA NA NA NA NA
MID
HIGH
vlinder Vendor ID (PGVPID)
LOW NA NA NA NA NA
MID
HIGH
Cvlinder Expiration Date
LOW NA NA NA NA NA
MID
HIGH
Cvlinder EPA Gas Type Code
LOW ZERO ZERO ZERO ZERO NA NA
MID NA NA
HIGH NA NA
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!FC-:\ CAI ^i-'alr I
Location:
Source:
Project No.:
Dete:
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Perameter o2 CO:SOt NOx CO H2S
Eroected Averape Concentrrtion
Span Should be between:
Low
High
Desired Soan
Low Range Gas Should be between
Low
Hish
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
Mid Range Gas Should be between
Low
Hioh
High Renge Ges Should be between
Low
Hish
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
Actuel Concentration (7o or ppm)
Zero
Low
Mid
Hiph
0.00
NA
000
NA
000
i1
000
NA
000
NA
000
NA
ResDonse Time (seconds)
Upscele Calibretion Gas (Cur)Mid Mid Mid Mid Mid Mid
Instrument Response (% or ppm)
Zero
Low
Mid
Hish
NA NA NA NA NA NA
Pcrformance (7o of Span or Calibretion
Zero
Low
Mid
Hioh
Ges)
NA NA NA NA NA NA
Linearity (7o of Spen or Cal. Gas Conc.
Jtatus
Zeto
Low
Mid
Hich
NA NA NA NA NA NA
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Location:
Source:
Project No.:
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Piremeter o,CO,SO,NOx CO H2S
Run I
Span Value
lnitial Instrument Zero Cal Response
Initial Instrument Upscale Cal Response
Final Instrument Zero Cal Response
Final Instrument Upscale Cal Response
Pretest System Zero Response
Posttest System Zero Response
Pretest System Mid Response
Posttest System Mid Response
Bias or System Performance (%)
Pretest Zero
Posttest Zero
Pretest Span
Posttest Span
NA
NA
NA
NA
Drift (%)
Zero
Mid
Run 2
Span Value
Initial Instrument Zero C al Response
Initial Instrument Upscale Cal Response
Finaf Instrument Zero Cal Response
Final Instrument Upscale Cal Response
Pretest System Zero Response
Posttest System Zero Response
Pretest System Mid Response
Posttest Svstem Mid Resoonse
Bias (%)
Pretest Zero
Posttest Zero
Pretest Span
Posttest Span
NA
NA
NA
NA
Drifr (%)
Zero
Mid
Run 3
Span Value
Initial InstrumentZerc Cal Response
Initial Instrument Upscale Cal Response
Final Instrument Zero Cal Response
Final Instrument Upscale Cal Response
Pretest System Zero Response
Posttest System Zero Response
Pretest System Mid Response
Posttest Svstem Mid Resnonse
Bias (%)
Pretest Zero
Posttest Zero
Pretest Span
Posttest Soan
NA
NA
NA
NA
Drift (%)
Zero
Mid
l__r Aliarrce
I SOUBCE TESTING
Locetion: --
QA/QC
I ""iffi'=
Device GC.FPD
Weke
tlodel
i/N
Comoound Boule ID Concenlration Mol./wt.
H2S 34.08
I arlArce
Location --
t ,-,.tffi=
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rime:
Cal QA
Date:
H2S
Conc. (ppm)
High Level Calibration Standard
Conc. (ppm)
Mid Level Calibration Standard
Iniection RT AC % Variation RT AC % Variation
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Mean
Notes:
***Calibration injections are reanalyzed using the calibration curve*'"No injeciton can vary from the mean of all 3 injections by >5%
***Chromatograms from calilbration injections are contained in the appendix
Alhrrce
STJL]I]CE IFSTING
Location: -
Recovery-Drift QA
Source: --
Project No.: -
GC Drift (Using H2S Gas)
Pre-Tesl Post-Test
Date Datr
Timr Time
Iniection #Measured Concentration (ppm)% l'ariation Measured Concentration (ppm)ol Variation o/o Drift
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3
Mean
=AlErrce
SOL]RCF T:STING
Location: --
Injection Start Time HzS
Run I Data
UTAH DEPARTMENT OF
Source: --
Project No.: --
Date:
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3
4
5
6
7
8
9
10
ll
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13
l4
l5
l6
t7
l8
l9
20
2t
22
23
24
25
26
27
28
29
30
ENVIRONMENTAL QUALIry
lir AY 1 ?- 20?5
Parameter HuS
Uncorrected Run Average (Co6.)
Corrected Run Averase (Corr)
DIVISION OF AIR OI'AI ITY