HomeMy WebLinkAboutDAQ-2024-0081691
DAQC-510-24
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 23, 2024
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-AN101190101-21 dated July 14, 2021
40CFR60 Subparts J/Ja
40CFR63 Subpart UUU
Subject: Review of RA/PST Protocol received May 20, 2024
On May 20, 2024, 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
19-26, 2024, to determine the relative accuracy of the H2S 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
9. RM 19 used to determine volumetric flow: OK
1 8 2
2
DEVIATIONS: No deviations were noted.
CONCLUSION: The protocol appears to be acceptable.
RECOMMENDATION: Send attached protocol review and test date confirmation notice.
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 19 – 23 & 26, 2024
Project No. AST-2024-1814-001
Prepared By
Alliance Technical Group, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120
Site Specific Test Plan
Test Program Summary
AST-2024-2436-001 Chevron – North Salt Lake, UT Page i
Regulatory Information
Permit No. UDAQ DAQE-AN 101190106-22
Regulatory Citations 40 CFR 60, Appendix B, Performance Specifications 2, 3, 4/4A, 6 and 7
40 CFR 60 J, 40 CFR 60 Ja, 40 CFR 63, UUU
NSPS Db
Source Information
Source Name Source ID Target Parameters
SRU and Tail Gas Incinerator #1 SRU1 VFR, O2, SO2
SRU and Tail Gas Incinerator #2 SRU2 VFR, O2, SO2
Catalyst Regenerator / Fluidized Catalytic
Cracking Unit (FCCU) and Catalyst
Regenerator
FCC O2, CO2, SO2, NOx, CO
F-11007 Boiler 7 O2, NOx
Alkylation Flare / Alkylation Flare Flare 3 H2S
RFG / Refinery Fuel Gas Mix Point Refinery Fuel Gas H2S
Contact Information
Test Location Test Company
Chevron Products Company
Salt Lake City Refinery
685 South Chevron Way
North Salt Lake, Utah 84054
Facility Contacts
Tony Pollock
dltf@chevron.com
(801) 539-7162
Alliance Technical Group, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120
Project Manager
Charles Horton
charles.horton@alliancetg.com
(352) 663-7568
Field Team Leader
Tobias Hubbard
tobias.hubbard@alliancetg.com
(605) 645-8562
(subject to change)
QA/QC Manager
Kathleen Shonk
katie.shonk@alliancetg.com
(812) 452-4785
Test Plan/Report Coordinator
Delaine Spangler
delaine.spangler@alliancetg.com
Site Specific Test Plan
Table of Contents
AST-2024-2436-001 Chevron – North Salt Lake, UT Page ii
TABLE OF CONTENTS
1.0 Introduction ................................................................................................................................................. 1-1
1.1 Facility Descriptions ................................................................................................................................... 1-1
1.2 CEMS Descriptions ..................................................................................................................................... 1-1
1.3 Project Team ............................................................................................................................................... 1-2
1.4 Safety Requirements ................................................................................................................................... 1-2
2.0 Summary of Test Program .......................................................................................................................... 2-1
2.1 General Description ..................................................................................................................................... 2-1
2.2 Process/Control System Parameters to be Monitored and Recorded .......................................................... 2-1
2.3 Proposed Test Schedule............................................................................................................................... 2-1
2.4 Emission Limits........................................................................................................................................... 2-3
2.5 Test Report .................................................................................................................................................. 2-4
3.0 Testing Methodology .................................................................................................................................. 3-1
3.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate ........ 3-1
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide .............................................................. 3-1
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 – Total Reduced Sulfur .................................................................... 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 3A, 6C, 7E and 10 .............. 3-3
4.0 Quality Assurance Program ......................................................................................................................... 4-1
4.1 Equipment ................................................................................................................................................... 4-1
4.2 Field Sampling ............................................................................................................................................ 4-2
LIST OF TABLES
Table 1-1: Project Team ........................................................................................................................................... 1-2
Table 2-1: Program Outline and Tentative Test Schedule ........................................................................................ 2-2
Table 2-2: Relative Accuracy Requirements and Limits .......................................................................................... 2-3
Table 3-1: Source Testing Methodology .................................................................................................................. 3-1
LIST OF APPENDICES
Appendix A Method 1 Field Data Sheet
Appendix B Example Field Data Sheets
Site Specific Test Plan
Introduction
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 1-1
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, 4/4A, 6 and 7, 40 CFR 60 J, 40 CFR 60 Ja, 40 CFR 63, UUU,
the Utah Department of Environmental Quality, Division of Air Quality (UDAQ) Permit No. DAQE-AN
101190106-22, and NSPS Db. Testing will include conducting a relative accuracy test audit (RATA) to determine
the relative accuracy (RA) of the oxygen (O2) and sulfur dioxide (SO2) continuous emissions monitoring systems
(CEMS) and the volumetric flow rate (VFR) continuous emissions rate monitoring systems (CERMS) installed on
the SRU/TGTU/TGU #1 / SRU and Tail Gas Incinerator #1 (SRU1) and SRU/TGTU/TGU #2 / SRU and Tail Gas
Incinerator #2 (SRU2). Testing will also include conducting a RATA to determine the RA of the O2, carbon dioxide
(CO2), SO2, nitrogen oxides (NOx), and carbon monoxide (CO) CEMS installed on the Catalyst Regenerator /
Fluidized Catalytic Cracking Unit and Catalyst Regenerator (FCC). Testing will include conducting a RATA to
determine the RA of O2 and NOx CEMS installed on the F-11007 (Boiler 7). Testing will also include conducting a
RATA to determine the RA of the hydrogen sulfide (H2S) CEMS installed on the Alkylation Flare / Alkylation Flare
(Flare 3) and RFG / Refinery Fuel Gas Mix Point (Refinery Fuel Gas).
This Continuous Emissions Monitoring System Relative Accuracy Test Protocol has been prepared to address the
notification and testing requirements of the UDAQ permit.
1.1 Facility Descriptions
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
SRU1
O2 SO2 Flow Rate
Make: Ametek Ametek Optical Scientific
Model: 9900 9900 OFS-2000
Serial No.: ZW-9900-S1332-1 ZW-9900-S1332-1 0502166E
Range: 0 – 10% 0 – 500 ppm 0 – 66 FPS
SRU2
O2 SO2 Flow Rate
Make: Ametek Ametek Thermox
Model: 9900 9900 OFS – 2000
Serial No.: AV-9000WM-10235-1A AV-9000WM-10235-1A 9080423
Range: 0 – 25% 0 – 500 ppm 0 – 66 FPS
Site Specific Test Plan
Introduction
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 1-2
FCC
O2 SO2 NOx CO
Make: Siemens Siemens Western
Research Siemens
Model: Ultramat/Oxymat Ultramat 922 NOx Ultramat
Serial No.: J7-447 J6-783 ZW-9900-1334-1 J6-783
Range: 0 – 10% 0 – 200 ppm 0 – 200 ppm 0 – 1000 ppm
Boiler 7
O2 NOx
Make: Ametek Ametek
Model: 9900 9900
Serial No.: ZE9900-10941-1 ZE9900-10941-1
Range: 0 - 21% 0 - 500 ppm
Flare 3
H2S
Make: Siemens
Model: Maximum II
Serial No.: OKB30068232740010
Range: 0 – 300 ppm
Refinery Fuel Gas
H2S
Make: Siemens
Model: Maxim II
Serial No.: 30019536380010
Range: 0 – 300 ppm
1.3 Project Team
Personnel planned to be involved in this project are identified in the following table.
Table 1-1: Project Team
Chevron Personnel Tony Pollock
Regulatory Agency UDAQ
Alliance Personnel Tobias Hubbard
other field personnel assigned at time of testing event
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 harnesses). 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 H2S, SO2, O2, and CO
levels while onsite.
A Job Safety Analysis (JSA) will be completed daily by the Alliance Field Team Leader.
Site Specific Test Plan
Summary of Test Programs
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 2-1
2.0 Summary of Test Program
To satisfy the requirements of UDAQ permit AN 101190106-22, 40 CFR 60, Appendix B, PS 2, 3, 4/4A, 6 and 7, 40
CFR 60 J, 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 SRU1, 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 1, 2,
3A, 4, 6C, 7E, 10, 15, and 19. Table 2-1 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 101190106-22 and 40 CFR
60, Appendix B, PS 2, 3, 4/4A, 6 and 7, 40 CFR 60 J, 40 CFR 60 Ja, and 40 CFR 63, UUU.
• Emissions testing will be conducted on the exhaust of SRU1, 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 nine to twelve (9-12) test runs will be 21 – 30-minutes in duration for the target parameter
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 2-1 presents an outline and tentative schedule for the emissions testing program.
Site Specific Test Plan
Summary of Test Programs
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 2-2
Table 2-1: Program Outline and Tentative Test Schedule
Testing Location Parameter US EPA Method No. of Runs Run Duration Est. Onsite
Time
August 19, 2024
Equipment Setup & Pretest QA/QC Checks 10 hr
Refinery Fuel Gas H2S 15 9-12 30 min 10 hr
August 20, 2024
Flare 3 H2S 15 9-12 30 min 10 hr
August 21, 2024
SRU1
VFR 1 & 2
9-12 21 min 10 hr O2/CO2 3A
SO2 6C
BWS 4 3-4 60 min
August 22, 2024
SRU2
VFR 1 & 2
9-12 21 min 10 hr O2/CO2 3A
SO2 6C
August 23, 2024
Boiler 7
O2/CO2 3A
9-12 21 min 10 hr NOx 7E
EF 19
August 24-25, 2024
Test Team Off
August 26, 2024
FCC
VFR 1 & 2
9-12 21 min 10 hr
O2/CO2 3A
SO2 6C
NOx 7E
CO 10
BWS 4 3-4 60 min
Site Specific Test Plan
Summary of Test Programs
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 2-3
2.4 Emission Limits
Emission limits for each pollutant are below.
Table 2-2: Relative Accuracy Requirements and Limits
Source CEMS Required Relative
Accuracy
Applicable Standard /
Limit Citation
SRU1
VFR ≤20 % (RM) -- 60, Appendix B, PS 6
O2 ≤20 % (RM) or ± 1 % O2
(avg. diff.) -- 60, Appendix B, PS 3
SO2 ≤20% of RM or
≤10 % of AS 250 ppmvd 60, Appendix B, PS 2
SRU2
VFR ≤20 % (RM) -- 60, Appendix B, PS 6
O2 ≤20 % (RM) or ± 1 % O2
(avg. diff.) -- 60, Appendix B, PS 3
SO2 ≤20% of RM or
≤10 % of AS 250 ppmvd 60, Appendix B, PS 2
FCC
O2 ≤20 % (RM) or ± 1 % O2
(avg. diff.) -- 60, Appendix B, PS 3
CO2 ≤20 % (RM) or ± 1 % CO2
(avg. diff.) -- 60, Appendix B, PS 3
SO2 ≤20% of RM or
≤10 % of AS 50 ppmvd 60, Appendix B, PS 2
NOx ≤20% of RM or
≤10 % of AS 160 ppmvd 60, Appendix B, PS 2
CO
≤20% of RM or
≤10 % of AS or
≤5 ppm of difference plus
the confidence coefficient
500 ppmvd 60, Appendix B, PS 44A
Boiler 7 O2 ≤20 % (RM) or ± 1 % O2
(avg. diff.) -- 60, Appendix B, PS 3
NOx ≤20 % (RM) or ≤10 % (AS) 106 ppmvd 60, Appendix B, PS 2
Flare 3 H2S ≤20 % (RM) or ≤10 % (AS) 162 ppmv 60, Appendix B, PS 7
40 CFR 60 Ja
Refinery Fuel
Gas H2S ≤20 % (RM) or ≤10 % (AS) 162 ppmv 60, Appendix B, PS 7
40 CFR 60 Ja
Site Specific Test Plan
Summary of Test Programs
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 2-4
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 SRU1, SRU2 for SO2 and FCC for CO.
• 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.
• Methodology – 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.
• Quality Control Data – Copies of all instrument calibration data and/or calibration gas certificates.
• Process Operating/Control System Data – Process operating and control system data (as provided by
Chevron) to support the test results.
Site Specific Test Plan
Testing Methodology
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 3-1
3.0 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. All 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 3-1: Source Testing Methodology
Parameter U.S. EPA Reference
Test Methods Notes/Remarks
Volumetric Flow Rate 1 & 2 Full Velocity Traverses
Oxygen/Carbon Dioxide 3A Instrumental Analysis
Moisture Content 4 Gravimetric Analysis
Sulfur Dioxide 6C Instrumental Analysis
Nitrogen Oxides 7E Instrumental Analysis
Carbon Monoxide 10 Instrumental Analysis
Hydrogen Sulfide 15 Instrumental Analysis
Mass Emission Factors 19 Fuel Factors/Heat Inputs
Gas Dilution System Certification 205 ---
All stack diameters, depths, widths, upstream and downstream disturbance distances and nipple lengths will be
measured on site with an EPA Method 1 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 1 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 1. To determine the minimum number of traverse points, the upstream and downstream
distances will be equated into equivalent diameters and compared to Figure 1-2 in U.S. EPA Reference Test Method
1.
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 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 Specification 6.
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide
The oxygen (O2) 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
Site Specific Test Plan
Testing Methodology
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 3-2
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 O2 and CO2 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 (SO2) 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 system
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 SO2 CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specification 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
heated Teflon sample line will be used. The quality control measures are described in Section 3.10.
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 10 – 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
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.
Site Specific Test Plan
Testing Methodology
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 3-3
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 15 – Total Reduced Sulfur
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 first two (2) impingers will contain 100 mL of citrate buffer (for SO2 removal) and the last will be
empty. The bag samples will be analyzed with a gas chromatograph (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 CS2) 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 15 requirements.
The relative accuracy of the H2S CEMS will be determined based on procedures found in 40 CFR 60, Appendix B,
Performance Specification 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 O2 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 1 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 recorded in an electronic field data sheet. The analyzer response
must agree within 2% of the actual diluted gas concentration. A second Protocol 1 calibration gas, with a cylinder
concentration within 10% 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.
3.10 Quality Assurance/Quality Control – U.S. EPA Reference Test Methods 3A, 6C, 7E and 10
Cylinder calibration gases will meet EPA Protocol 1 (+/- 2%) standards. Copies of all calibration gas certificates
will be included in the Quality 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
Site Specific Test Plan
Testing Methodology
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 3-4
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 ppmv/% 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 ppm/%
(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/% absolute difference or the data is invalidated, and the Calibration
Error Test and System Bias must be repeated.
The Drift between 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 do not differ more than 5% or 0.5 ppm/0.3% (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 10% 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 10% 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 NO2 – 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
the instrument response will be recorded in an electronic data sheet. The instrument response must be within +/- 10
percent of the cylinder concentration.
A Data Acquisition System with battery backup will be used to record the instrument response in one (1) 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
Site Specific Test Plan
Testing Methodology
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 3-5
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.
Site Specific Test Plan
Quality Assurance Program
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 4-1
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-94/038c, September 1994) are 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.
• 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 (ΔH@). Alliance uses approved
Alternative Method 009 as a post-test calibration check to ensure that the correction factor has not changed
more than 5% since the last full meter calibration. This check is performed after each test series.
• 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.
• Temperature Measuring Devices. All thermocouple sensors mounted in Dry Gas Meter Consoles are
calibrated semi-annually with a NIST-traceable thermocouple calibrator (temperature simulator) and
verified during field use using a second NIST-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.
• Digital Calipers. Calipers are calibrated annually by Alliance by using gage blocks that are calibrated
annually by an outside laboratory.
Site Specific Test Plan
Quality Assurance Program
AST-2024-2436-001 Chevron – North Salt Lake, UT Page 4-2
• 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 use 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.
• 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, ΔP, ΔH, temperature and pump vacuum data will be recorded during each sample point.
• An isokinetic sampling rate of 90-110% will be maintained, as applicable.
• All raw data will be maintained in organized manner.
• All raw data will be reviewed on a daily basis for completeness and acceptability.
Appendix A
Method 1 Data
Location
Source
Project No.
Date:
in
in
0.00 in
--in
--ft2
--in
ft
--(must be ≥ 0.5)
ft
--(must be ≥ 2)
--
Measurer (Initial and Date):
Reviewer (Initial and Date):
23456789101112
1 25.0 16.7 12.5 10.0 8.3 7.1 6.3 5.6 5.0 4.5 4.2 1 -- -- --
2 75.0 50.0 37.5 30.0 25.0 21.4 18.8 16.7 15.0 13.6 12.5 2 -- -- --
3 -- 83.3 62.5 50.0 41.7 35.7 31.3 27.8 25.0 31.8 20.8 3 -- -- --
4 -- -- 87.5 70.0 58.3 50.0 43.8 38.9 35.0 22.7 29.2 4 -- -- --
5 -- -- -- 90.0 75.0 64.3 56.3 50.0 45.0 40.9 37.5 5 -- -- --
6 -- -- -- -- 91.7 78.6 68.8 61.1 55.0 50.0 45.8 6 -- -- --
7 -- -- -- -- -- 92.9 81.3 72.2 65.0 59.1 54.2 7 -- -- --
8 -- -- -- -- -- -- 93.8 83.3 75.0 68.2 62.5 8 -- -- --
9 -- -- -- -- -- -- -- 94.4 85.0 77.3 70.8 9 -- -- --
10 -- -- -- -- -- -- -- -- 95.0 86.4 79.2 10 -- -- --
11 -- -- -- -- -- -- -- -- -- 95.5 87.5 11 -- -- --
12 -- -- -- -- -- -- -- -- -- -- 95.8 12 -- -- --
*Percent of stack diameter from inside wall to traverse point.
A = ft.
B = ft.
Depth of Duct = 0 in.
Number of traverse points on a diameter
Stack Diagram
Cross Sectional Area
LOCATION OF TRAVERSE POINTS
Traverse
Point
% of
Diameter
Distance
from inside
wall
Distance
from
outside of
port
Equivalent Diameter:
No. of Test Ports:
Number of Readings per Point:
Distance A:
Distance A Duct Diameters:
Distance B:
Distance B Duct Diameters:
Minimum Number of Traverse Points:
Actual Number of Traverse Points:
DUCT
Duct Design:
Nipple Length:
Depth of Duct:
Width of Duct:
Cross Sectional Area of Duct:
Distance from Far Wall to Outside of Port:
Duct Orientation:
--
--
--
Stack Parameters
Upstream
Disturbance
Downstream
Disturbance
BA
Appendix B
SO2 Summary
Location:
Source:
Project No.:
Reference Method CEMS Average
SO2 Concentration SO2 Concentration Difference
Start End ppmvd @ 3 % O2 ppmvd @ 3 % O2 ppmvd @ 3 % O2
1 -- --
2 -- --
3 -- --
4 -- --
5 -- --
6 -- --
7 -- --
8 -- --
9 -- --
10 -- --
11 -- --
12 -- --
-
RA ≤ 20%
PS 2
Confidence Coefficient, CC
where,
t0.975 #N/A = degrees of freedom value
n 0 = number of runs selected for calculating the RA
Sd = standard deviation of difference
CC = confidence coefficient
Relative Accuracy, RA
where,
d = average difference of Reference Method and CEMS
CC = confidence coefficient
RM = reference method, ppmvd @ 3 % O2
RA = relative accuracy, %
Relative Accuracy (RA)
Performance Required - Mean Reference Method
Performance Specification Method
Run
No.Date Time
Average
Standard Deviation (Sd)
Applicable Source Standard (AS)
Confidence Coefficient (CC)
CC ൌ t.ଽହ
n ൈ 𝑆d
RA ൌ d 𝐶𝐶
𝐴𝑆 𝑜𝑟 𝑅𝑀ൈ 100
NOx Summary
Location:
Source:
Project No.:
Reference Method CEMS Average
NOx Concentration NOx Concentration Difference
Start End ppmvd @ 3 % O2 ppmvd @ 3 % O2 ppmvd @ 3 % O2
1 -- --
2 -- --
3 -- --
4 -- --
5 -- --
6 -- --
7 -- --
8 -- --
9 -- --
10 -- --
11 -- --
12 -- --
-
RA ≤ 20%
PS 2
Confidence Coefficient, CC
where,
t0.975 #N/A = degrees of freedom value
n 0 = number of runs selected for calculating the RA
Sd = standard deviation of difference
CC = confidence coefficient
Relative Accuracy, RA
where,
d = average difference of Reference Method and CEMS
CC = confidence coefficient
RM = reference method, ppmvd @ 3 % O2
RA = relative accuracy, %
Relative Accuracy (RA)
Performance Required - Mean Reference Method
Performance Specification Method
Run
No.Date Time
Average
Standard Deviation (Sd)
Applicable Source Standard (AS)
Confidence Coefficient (CC)
CC ൌ t.ଽହ
n ൈ 𝑆d
RA ൌ d 𝐶𝐶
𝐴𝑆 𝑜𝑟 𝑅𝑀ൈ 100
CO Summary
Location:
Source:
Project No.:
Reference Method CEMS Average
CO Concentration CO Concentration Difference
Start End ppmvd @ 3 % O2 ppmvd @ 3 % O2 ppmvd @ 3 % O2
1 -- --
2 -- --
3 -- --
4 -- --
5 -- --
6 -- --
7 -- --
8 -- --
9 -- --
10 -- --
11 -- --
12 -- --
-
RA ≤ 10%
PS 4A
Confidence Coefficient, CC
where,
t0.975 #N/A = degrees of freedom value
n 0 = number of runs selected for calculating the RA
Sd = standard deviation of difference
CC = confidence coefficient
Relative Accuracy, RA
where,
d = average difference of Reference Method and CEMS
CC = confidence coefficient
RM = reference method, ppmvd @ 3 % O2
RA = relative accuracy, %
Alternative Relative Accuracy, RA
where,
d = average difference of Reference Method and CEMS
CC = confidence coefficient
RA -- = relative accuracy, ppm
Relative Accuracy (RA)
Performance Required - Mean Reference Method
Performance Specification Method
Run
No.Date Time
Average
Standard Deviation (Sd)
Applicable Source Standard (AS)
Confidence Coefficient (CC)
CC ൌ t.ଽହ
n ൈ 𝑆d
RA ൌ d 𝐶𝐶
𝐴𝑆 𝑜𝑟 𝑅𝑀ൈ 100
RA ൌ d 𝐶𝐶
H2S Summary
Location:
Source:
Project No.:
Reference Method CEMS Average
H2S H2S Difference
Start End ppmvd ppmvd ppmvd
1---- --
-- --
2---- --
-- --
3---- --
-- --
4---- --
-- --
5---- --
-- --
6---- --
-- --
7---- --
-- --
8---- --
-- --
9---- --
-- --
10 ---- --
-- --
11 ---- --
-- --
12 ---- --
-- --
162
≤ 20%
PS 7 (RM 15)
Confidence Coefficient, CC
where,
t0.975 #N/A = degrees of freedom
n 9 = number of runs selected for calculating the RA
Sd = standard deviation of difference
CC = confidence coefficient
Relative Accuracy, RA
where,
mean difference = average difference of Reference Method and CEMS
t0.975 #N/A = degrees of freedom
n 9 = number of runs selected for calculating the RA
Sd = standard deviation of difference
RM = reference method
RA = relative accuracy
-
-
-
Run
No.Date Time
Performance Specification Method
Average
Standard Deviation (Sd)
Applicable Source Standard (AS)
Confidence Coefficient (CC)
Relative Accuracy (RA)
Acceptability Criteria - Mean Reference Method
VFR Summary
Location:
Source:
Project No.:
Reference Method CEMS Average
Flow Rate Flow Rate Difference
Start End dscfm dscfm dscfm
1 -- 0:00 0:00 -- --
2 -- 0:00 0:00 -- --
3 -- 0:00 0:00 -- --
4 -- 0:00 0:00 -- --
5 -- 0:00 0:00 -- --
6 -- 0:00 0:00 -- --
7 -- 0:00 0:00 -- --
8 -- 0:00 0:00 -- --
9 -- 0:00 0:00 -- --
10 -- 0:00 0:00 -- --
11 -- 0:00 0:00 -- --
12 -- 0:00 0:00 -- --
--
-
≤ 20%
PS 6
Confidence Coefficient, CC
where,
t0.975 #N/A = degrees of freedom value
n 0 = number of runs selected for calculating the RA
Sd = standard deviation of difference
CC = confidence coefficient
Relative Accuracy, RA
where,
d = average difference of Reference Method and CEMS
CC = confidence coefficient
RM - = reference method, dscfm
RA = relative accuracy, %
-- - --
--
--
Run
No.Date Time
Average
Standard Deviation (Sd)
Confidence Coefficient (CC)
Relative Accuracy (RA)
Acceptability Criteria - Mean Reference Method
Performance Specification Method
CC ൌ t .ଽହ
n ൈ 𝑆d
RA ൌ d 𝐶𝐶
𝑅𝑀ൈ 100
Emissions Calculations
Location:
Source:
Project No.:
123456789101112
Date ------------
Start Time -- -- -- -- -- -- -- -- -- -- -- --
Stop Time -- -- -- -- -- -- -- -- -- -- -- --
Calculated Data
SO2 Concentration ppmvd CSO2 -- -- -- -- -- -- -- -- -- -- -- --
NOx Concentration ppmvd CNOx -- -- -- -- -- -- -- -- -- -- -- --
CO Concentration ppmvd CCO -- -- -- -- -- -- -- -- -- -- -- --
H2S Concentration ppmvd CH2S -- -- -- -- -- -- -- -- -- -- -- --
Run Number
-
-
-
Run 1 Data
Location:
Source:
Project No.:
Date:
Time O2 CO2 SO2 NOx CO H2S
Unit % dry % dry ppmvd ppmvd ppmvd ppmvw
Status Valid Valid Valid Valid Valid Valid
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
O2 CO2 SO2 NOx CO H2S
Uncorrected Run Average (Cobs)------
Cal Gas Concentration (CMA)-- -- -- -- -- --
Pretest System Zero Response
Posttest System Zero Response
Average Zero Response (Co)------
Pretest System Cal Response
Posttest System Cal Response
Average Cal Response (CM)------
Corrected Run Average (Corr)-----NA
Parameter
-
Diluent Pollutant
QA Data
Location:
Source:
Project No.:
O2 CO2 SO2 NOx CO H2S
------------
------------
--
Cylinder Number ID
LOW NA NA NA NA NA
MID
HIGH
Cylinder Certified Values
LOW NA NA NA NA NA
MID
HIGH
LOW NA NA NA NA NA --
MID --
HIGH --
LOW NA NA NA NA NA
MID
HIGH
Cylinder EPA Gas Type Code
LOW ZERO ZERO ZERO ZERO NA NA
MID NA NA
HIGH NA NA
Make
Model
S/N
Operating Range
Parameter
Cylinder Vendor ID (PGVPID)
Cylinder Expiration Date
Calibration Data
Location:
Source:
Project No.:
Date:
O2 CO2 SO2 NOx CO H2S
Expected Average Concentration ------------
Span Should be between:
Low ----- -
High ----- -
Desired Span ------------
Low Range Gas Should be between
Low NA NA NA NA NA NA
High NA NA NA NA NA NA
Mid Range Gas Should be between
Low ----- -
High ----- -
High Range Gas Should be between
Low NA NA NA NA NA NA
High NA NA NA NA NA NA
Actual Concentration (% or ppm)
Zero 0.00 0.00 0.00 0.00 0.00 0.00
Low NA NA NA NA NA NA
Mid ------------
High ------------
Response Time (seconds)------------
Upscale Calibration Gas (CMA)Mid Mid Mid Mid Mid Mid
Instrument Response (% or ppm)
Zero -- -- -- -- -- --
Low NA NA NA NA NA NA
Mid -- -- -- -- -- --
High -- -- -- -- -- --
Performance (% of Span or Calibration Gas)
Zero -- -- -- -- -- --
Low NA NA NA NA NA NA
Mid -- -- -- -- -- --
High -- -- -- -- -- --
Linearity (% of Span or Cal. Gas Conc.)
-- -- -- -- -- --
Status
Zero -- -- -- -- -- --
Low NA NA NA NA NA NA
Mid -- -- -- -- -- --
High -- -- -- -- -- --
Parameter
Runs 1-3 Bias/Drift Determinations
Location:
Source:
Project No.:
Date:
O2 CO2 SO2 NOx CO H2S
Span Value ------
Initial 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 -- -- -- -- -- NA
Posttest Zero -- -- -- -- -- NA
Pretest Span -- -- -- -- -- NA
Posttest Span -- -- -- -- -- NA
Drift (%)
Zero ------
Mid ------
Span Value ------
Initial 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 (%)
Pretest Zero -- -- -- -- -- NA
Posttest Zero -- -- -- -- -- NA
Pretest Span -- -- -- -- -- NA
Posttest Span -- -- -- -- -- NA
Drift (%)
Zero ------
Mid ------
Span Value ------
Initial 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 (%)
Pretest Zero -- -- -- -- -- NA
Posttest Zero -- -- -- -- -- NA
Pretest Span -- -- -- -- -- NA
Posttest Span -- -- -- -- -- NA
Drift (%)
Zero ------
Mid ------
Run 1
Run 2
Run 3
-
Parameter
QA/QC
Location:
Source:
Project No.:
GC-FPD
Make
Model
S/N
Bottle ID Concentration Mol./wt.
34.08
--
--
--
Device
Compound
H2S
Cal QA
Location
Source
Project No.
Date:
Time:
Conc. (ppm) Conc. (ppm)
Injection RT AC % Variation RT AC % Variation
1--
2--
3--
Mean -- -- -- --
***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
Notes:
--
--
--
H2S High Level Calibration Standard Mid Level Calibration Standard
Recovery-Drift QA
Location:
Source:
Project No.:
Pre-Test Post-Test
Date Date
Time Time
Injection #Measured Concentration (ppm)% Variation Measured Concentration (ppm)% Variation % Drift
1 ----
2 ----
3 ----
Mean -- -- --
--
--
--
GC Drift (Using H2S Gas)
Run 1 Data
Location:
Source:
Project No.:
Date:
Injection Start Time H2S
ppm
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Parameter H2S
Uncorrected Run Average (Cobs)--
Corrected Run Average (Corr)--
--
--
--