DAQ-2025-001061

1
DAQC-150-25
Site ID 10119 (B5)

MEMORANDUM

TO: FILE – CHEVRON PRODUCTS COMPANY – Salt Lake Refinery

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Rob Leishman, Environmental Scientist

DATE: February 6, 2025

SUBJECT: Chevron Products Company (Chevron), Major, NSPS, Title V, MACT, Davis County –
FRS # UT00000049001100003

INSPECTION TYPE: State Electronic Data Report (SEDR) Review

REVIEW DATE: February 6, 2025

SOURCE LOCATION: North Salt Lake/Davis County

SOURCE CONTACT: Tony Pollock – 801-539-7162

APPLICABLE
REGULATIONS: Approval Order (AO) DAQE-AN101190106-22, dated
August 24, 2022

SOURCE REVIEW
EVALUATION: With the exception of sources that only monitor for opacity, quarterly
report memoranda will only address the findings of the quarterly
report. Approval Order and Title V permit conditions addressing
continuous emission monitoring requirements will be addressed in
Chevron’s relative accuracy performance specification test review
memorandum.

SEDR REVIEW:

Fourth Quarter 2024
% Monitor Availability (MA) Performance Test Dates
(N/A to Opacity)
Summary of Excess Emissions During Point
Source Operation
Point
Source
Op.
hrs. Channel MA CGA Lin RATA Point
Source Channel Hrs. Limitation
Boiler #7 2208 NOx 99% 11/06/24 08/27/24
FCC
Regenerator
Vent
Opacity 0.00 30 % - 6min
Boiler #7 2208 O2 99% 11/06/24 08/27/24
FCC
Regenerator
Vent
Opacity 0.00 20 % - 3hrRA

1 8 2

2
Fourth Quarter 2024
% Monitor Availability (MA) Performance Test Dates
(N/A to Opacity)
Summary of Excess Emissions During Point
Source Operation
Point
Source
Op.
hrs. Channel MA CGA Lin RATA Point
Source Channel Hrs. Limitation
FCC
Regenerator
Vent
2208 Opacity 100%
FCC
Regenerator
Vent
SO2 0.00 50 ppm -
7dRA
FCC
Regenerator
Vent
2208 CO 96% 11/07/24 08/26/24
FCC
Regenerator
Vent
SO2 0.00 25 ppm -
365dRA
FCC
Regenerator
Vent
2208 NOx 96% 11/07/24 08/26/24
FCC
Regenerator
Vent
NOx 0.00 106 ppm -
7dRA
FCC
Regenerator
Vent
2208 SO2 96% 11/07/24 08/26/24
FCC
Regenerator
Vent
NOx 0.00 80 ppm -
7dRA
FCC
Regenerator
Vent
2208 CO2 96% 11/07/24 08/26/24
FCC
Regenerator
Vent
CO 0.00 500 ppm -
hour
FCC
Regenerator
Vent
2208 O2 96% 11/08/24 08/26/24 Flare #1 H2S 1.00 162 ppm -
3hrRA
Flare #1 2208 H2S 98% 11/05/24 09/21/20 Flare #2 H2S 6.00 162 ppm -
3hrRA
Flare #1 2208 TRS 98% 11/05/24 Flare #3 H2S 0.00 162 ppm -
3hrRA
Flare #2 2208 H2S 99% 11/07/24 09/22/20 Fuel Gas
Mix Point H2S 0.00 162 ppm -
3hrRA
Flare #2 2208 TRS 99% 11/07/24 Fuel Gas
Mix Point H2S 0.00 60 ppm -
365dRA
Flare #3 2208 H2S 99% 12/12/24 08/20/24 SRU Tailgas
Incinerator 1 SO2 138.00 250 ppm -
12hrRA
Flare #3 2208 TRS 97% 12/12/24 SRU Tailgas
Incinerator 2 SO2 445.00 250 ppm -
12hrRA
Fuel Gas
Mix Point 2208 H2S 98% 11/06/24 08/19/24
SRU Tailgas
Incinerator 1 2208 SO2 100% 11/04/24 08/21/24
SRU Tailgas
Incinerator 1 2208 O2 100% 11/04/24 08/21/24
SRU Tailgas
Incinerator 2 2208 SO2 98% 11/05/24 08/22/24
SRU Tailgas
Incinerator 2 2208 O2 98% 11/05/24 08/22/24

Excess Emission Report - Hourly Summary
Point
Source Channel
Startup
&
Shutdown
Control
Equipment
Problems
Process
Problems
Other
Known
Causes
Unknown
Causes
Emission
Limit
FCC Regenerator Vent Opacity 0 0 0 0 0 30 % - 6min
FCC Regenerator Vent Opacity 0 0 0 0 0 20 % - 3hrRA
FCC Regenerator Vent SO2 0 0 0 0 0 50 ppm - 7dRA

3
Excess Emission Report - Hourly Summary
Point
Source Channel
Startup
&
Shutdown
Control
Equipment
Problems
Process
Problems
Other
Known
Causes
Unknown
Causes
Emission
Limit
FCC Regenerator Vent SO2 0 0 0 0 0 25 ppm - 365dRA
FCC Regenerator Vent NOx 0 0 0 0 0 106 ppm - 7dRA
FCC Regenerator Vent NOx 0 0 0 0 0 80 ppm - 7dRA
FCC Regenerator Vent CO 0 0 0 0 0 500 ppm - hour
Flare #1 H2S 0 1 0 0 0 162 ppm - 3hrRA
Flare #2 H2S 0 6 0 0 0 162 ppm - 3hrRA
Flare #3 H2S 0 0 0 0 0 162 ppm - 3hrRA
Fuel Gas Mix Point H2S 0 0 0 0 0 162 ppm - 3hrRA
Fuel Gas Mix Point H2S 0 0 0 0 0 60 ppm - 365dRA
SRU Tailgas
Incinerator 1 SO2 0 0 138 0 0 250 ppm - 12hrRA
SRU Tailgas
Incinerator 2 SO2 0 0 437 8 0 250 ppm - 12hrRA

CMS Performance Summary - Hourly Summary
Point
Source Channel Monitor
Malfunction
Non-monitor
Malfunction
QA
Calibrations
Other
Known
Causes
Unknown
Causes
Boiler #7 NOx 29 0 0 1 0
Boiler #7 O2 29 0 0 1 0
FCC Regenerator Vent Opacity 0 0 0 2 0
FCC Regenerator Vent CO 40 1 47 3 0
FCC Regenerator Vent NOx 40 1 47 3 0
FCC Regenerator Vent SO2 44 1 47 3 0
FCC Regenerator Vent CO2 40 1 47 3 0
FCC Regenerator Vent O2 40 1 47 3 0
Flare #1 H2S 10 0 23 3 0
Flare #1 TRS 27 15 0 3 0
Flare #2 H2S 0 0 23 1 0
Flare #2 TRS 0 30 0 1 0
Flare #3 H2S 3 0 25 1 0
Flare #3 TRS 35 0 0 26 0
Fuel Gas Mix Point H2S 0 0 39 1 0
SRU Tailgas Incinerator 1 SO2 0 0 0 1 0
SRU Tailgas Incinerator 1 O2 0 0 0 1 0
SRU Tailgas Incinerator 2 SO2 48 0 0 1 0
SRU Tailgas Incinerator 2 O2 48 0 0 1 0

4
Type Code 280 (COMS Attenuator Filters) Procedure 3
Point Source &
Location Attenuator I.D.
Attenuator
Certification
Date
Certified
Attenuator
Opacity
OPLR,
SECR,
or
PLCF
Corrected
Opacity
Value
Range
Low,
Mid,
&
High
Certification
1-year or
5-year
FCC Regenerator Vent
Flue Gas Duct DHT200 /14108330 3/4/24 12.90 0.90 21.68 Low 1 Year
FCC Regenerator Vent
Flue Gas Duct DHT200 /14108330 3/4/24 24.60 0.90 39.4 Mid 1 Year
FCC Regenerator Vent
Flue Gas Duct DHT200 /14108330 3/4/24 36.80 0.90 55.33 High 1 Year

Type Code 281 (Procedure 3 - COMS Filter Audit Calibration Error)
Point
Source Location Audit
Date
Opacity Monitor
Response
(Average of 5) Mean
Difference
Calibration
Error (≤ 3%)
Low Mid High
FCC Regenerator Vent Flue Gas Duct 11/6/24 7 0.790 1.297
FCC Regenerator Vent Flue Gas Duct 11/6/24 7 0.450 0.877
FCC Regenerator Vent Flue Gas Duct 11/6/24 7 0.170 0.735

Pollutant Concentration
Exceeded Span of CEM
Monitor Outage During
Point Source Operation
Alternate
Sampling CEM Modifications
139 Hours 879 Hours 0 Hours 0 Events

SOURCE INSPECTION
SUMMARY EVALUATION: Chevron maintains its CEMS as required in R307-170 and 40 CFR
60.13.

CURRENT
RECOMMENDATIONS: All deviations appear to be a result of breakdown or process related
problems that do not warrant issuing a violation. Chevron was in
compliance during this reporting period. No further enforcement
actions should be taken. Chevron’s NSPS monitoring system meets
the performance standards of 40 CFR 60, Appendix B, Performance
Specifications.

HIGH PRIORITY
VIOLATOR (HPV): No

RECOMMENDATION
FOR NEXT INSPECTION: Check DAS for daily zero and span drift.
Check the QC program to ensure that monitor drift is being tracked
and that the source can identify excessive drift.

ATTACHMENTS: Excel spreadsheet review
ChevTon
Troy Tortorich Chevron Products Company
Refinery Manager Salt Lake Refinery
685 South Chevron Way
North Salt Lake, Utah 84054
Tel [phone]
January 27, 2024
CERTIFIED MAIL
RETURN RECEIPT #7018 0680 0001 4890 6637
Mr. Bryce Bird, Director
Division of Air Quality
Utah Department of Environmental Quality
4th QUARTER 2024 CEM REPORT - State Electronic Data Report (SEDR)
Dear Mr. Bird,
Chevron Products Company Salt Lake Refinery submits the Quarterly Report in ASCII Electronic Format
for the 4th quarter of 2024. This is in accordance with UACR 307-170 and applicable 40 CFR 60
subparts A, J, and Ja requirements. This report contains data on the following monitoring systems:
" Boiler 7 NOx 02 CEM
" FCC regenerator opacity COMS
" FCC regenerator CO, C02 NOx, SO2, and 02 CEM
" Fuel Gas 112S CEM
" Flare I H2S, TRS CEM
" Flare 2 H2S, TRS CEM
" Flare 3 H2S, TRS CEM
" SRU ISO2 and02CEM
" SRU2SO2andO2CEM
As per the EPA response letter attached, the approved alternative test method to the relative accuracy
test for H2S CEMS has been used at Flare I and Flare 2.
If you have any questions regarding the CEM Report, please contact Tony Pollock at 801-539-7162 or
dItfchevron.com.
I certilS' under penalty of law that all information contained in the report is truthful and accurate and is a
complete record of all monitoring related events which occurred during the 4th quarter of 2024.
Sincerely,
Troy Tortorich

Ms. Serena Yau
Chevron Salt Lake Refinery
685 South Chevron Way
North Salt Lake, Utah 84054

Dear Ms. Yau:
I am writing in response to your letter to EPA Region 8, dated October 27, 2020, in which you
seek an alternative test method for use on Flare1 and Flare 2 at Chevron’s Salt Lake Refinery
(Salt Lake) located in Salt Lake City, Davis County, Utah. It is our understanding that this
facility is subject to 40 CFR part 60, Subpart Ja, Standards of Performance for Petroleum
Refineries for Which Construction, Reconstruction, or Modification Commenced After May 14,
2007 (Subpart Ja). The Office of Air Quality Planning and Standards (OAQPS), as the delegated
authority, must make the determination on any major alternatives to test methods and procedures
required under 40 CFR parts 59, 60, 61, 63 and 65. Your proposed test method alternatives and
our approval decisions are discussed below.

According to the information provided, Flare 1 and Flare 2 at Salt Lake are subject to section
60.107a(a)(2) of Subpart Ja, which requires that a hydrogen sulfide (H2S) continuous monitoring
system (CEMS) be used to comply with the emission limits found in section 60.103a(h) of
Subpart Ja. Section 60.107a(a)(2) of Subpart Ja also requires an H2S CEMS be installed,
operated and maintained according to 40 CFR part 60, appendix B, Performance Specification 7
(PS-7), and the use of Method 11, 15, or 15A of Appendix A-5 to 40 CFR part 60 or Method 16
of Appendix A-6 to 40 CFR part 60 for conducting the relative accuracy test. Following section
60.107a(a)(2), you are required to comply with the applicable quality assurance procedures in
Appendix F to 40 CFR part 60, specifically Procedure 1 (40 CFR 60, Appendix F), which
requires the annual relative accuracy test of each H2S CEMS.

Based on the information you provided, Flare 1 and Flare 2 are both equipped with a flare vapor
recovery (FVR) system. These FVR systems employ a water seal to prevent flaring, unless there
is sufficient pressure on the seal for flare gas to break through. The vapors that do not break
through the water seal are compressed and recovered. The FVR system prevents flaring the vast
majority of the time. The H2S CEMS are located downstream of these water seals which means
that when these water seals are intact, which is typical, there is no flare gas being sampled by the
H2S CEMS. This intermittent flaring makes conducting a relative accuracy test on an H2S CEMS
on Flare 1 and Flare 2 difficult. As a result of the difficulty associated with conducting a relative
1/12/2021
2

accuracy test on these H2S CEMSs, you seek to use the alternative relative accuracy procedure
provided in section 16.2 of 40 CFR part 60, Appendix B, Performance Specification 2 (PS-2) and
referenced as an alternative to the relative accuracy test in sections 60.107a(e)(1)(ii) and (2)(ii)
of Subpart Ja. The alternative procedure requested allows for the completion of the alternative
relative accuracy procedures found in section 16.0 of PS-2 in lieu of the relative accuracy test
procedures for an H2S CEMS specified in PS-7.

We have reviewed your request and the associated rule language and recognize that it can be
difficult to perform relative accuracy tests of the H2S CEMSs installed on these units that do not
consistently combust flare gas. Based on the information contained in your request on the
intermittent flare gas flows, we approve the use of the alternative testing approach found in
section 16.0 of PS-2, which allows cylinder gases to be used as an alternative to the relative
accuracy test for H2S CEMSs, with the following caveats for each test:
• This alternative test method is only approved for use on the two H2S CEMSs installed on
Flare 1 and Flare 2 at Chevron’s Salt Lake Refinery.
• The alternative relative accuracy procedures approved herein are an alternative to the
relative accuracy test required by PS-7 and Procedure 1.
• When conducting the alternative relative accuracy test, you must follow the procedures
for performing the alternative relative accuracy test described in section 16.2 of PS-2 and
meet the criteria specified in section 16.3 of PS-2.
• The gas quality for the cylinder gases used to conduct the alternative relative accuracy
tests must meet the Protocol Gas requirements defined in section 16.2.4 of PS-2, to an
accuracy of at least 3 percent, or the cylinder gas material must be vendor certified as
traceable to a NIST standard at 3 percent accuracy if Protocol Gases are not available at
the concentration necessary for the alternative relative accuracy test.
• The alternative relative accuracy procedures must be performed periodically as defined in
section 60.107a(a)(1)(v) of Subpart Ja.
• A copy of this approval letter must be included in the report detailing the results of the
alternative relative accuracy procedures.

If you have any questions regarding this determination, please contact Kim Garnett at 919-541-
1158 or [e-mail].

Sincerely,

Steffan M. Johnson, Leader
Measurement Technology Group
STEFFAN
JOHNSON
Digitally signed by STEFFAN
JOHNSON Date: 2021.01.12 08:43:07 -05'00'
3

cc: Rachel Agnew, Chevron ([e-mail])
Kim Garnett, EPA/OAQPS/AQAD ([e-mail])
Jeremy Marsigli, Utah DEQ ([e-mail])
Laurie Ostrand, EPA R8 ([e-mail])
Brenda Shine, EPA/OAQPS/SPPD ([e-mail])

Chevron Refinery EER 4Q2024
Point Source Information Late Expired Cal. Gas Valid Cal. Gas Days Yes No
1 Type Code 100
(Company Information)Type Code Company Manager Company Name AIRS # Phone Number
Environmental
Contact1 100 Troy Tortorich 01100003 [phone] Tony Pollock
1 100 0 0 0 0
1 Type Code 110(Point Source Identification)Type Code Point Source
Quarter1 - 4 Year Point Source
Operating Hrs. in
Quarter
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 4 2024 2208
1 110 0 0 0
1 Type Code 200
(Monitor Identification)Type Code Point Source Channel Manufacturer Model No. Monitor SN Low Span High Span Installation Date
Monitor
Location1 200 NOx Ametek Western Research9900 ZE-9900-10941-10 500 8/17/2018 F11007
1 200 O2 Ametek Western Research9900 ZE-9900-10941-10 21 8/17/2018 F11007
1 200 CO Siemens Ultramat 6 J6-783 0 1000 4/16/2020 K3223
1 200 CO2 Siemens Ultramat 6/Oxymat 6J7-447 0 25 4/16/2020 K3223
1 200 NOx Ametek Western Research9900 ZW-9900-S1334-10 200 4/16/2020 K3223
1 200 O2 Siemens Ultramat 6/Oxymat 6J7-447 0 10 4/16/2020 K3223
1 200 Opacity Sick/Maihak DHT200 0 100 10/5/2013 K3223
1 200 SO2 Siemens Ultramat 6E J6-783 0 200 4/16/2020 K3223
1 200 H2S Siemens Maxum Edition II #300194969000100 300 2/3/2010 V75220
1 200 TRS Atom FGA-100 140011 0 250000 11/5/2015 V75220
1 200 H2S Siemens Maxum Edition II #300194969000200 300 11/5/2010 V75120
1 200 TRS Atom FGA-100 140012 0 250000 11/4/2015 V75120
1 200 H2S Siemens Maxum Edition II #30019469000200 300 11/6/2019 D35014
1 200 TRS Atom FGA-100 18002 0 250000 11/6/2019 D35014
1 200 H2S Siemens Maxum Edition II #30019536380010ump 300 12/6/2009 V-113
1 200 O2 Ametek Ametek 9900 ZW-9900-S1332-10 21 9/1/2021 F-6550
1 200 SO2 Ametek Ametek 9900 ZW-9900-S1332-10 500 9/1/2021 F-6550
1 200 O2 Ametek Ametek 9000 AV9000WM-10235-1A0 21 12/16/2010 F-68250
1 200 SO2 Ametek Ametek 9000 AV9000WM-10235-1A0 500 12/16/2010 F-68250
1 200 0 0 0 0 0 0 1/0/1900 0
1 Type Code310(Excess Emissions)SUMMARY REPORT
Type Code Channel Total Hours of Excess Emissions
Excess Emissions -
% of Total
Operating Hours
RC 701 Hours -
start
up/Shutdown
RC 702 Hours-
Control Equipment
Problems
RC 703 Hours -Process Problems
RC 704, 706, 707
Hours -Other Known
Causes
RC 705 Hours -
Unknown
Causes
Emission Limitation
Emission
Limitation
Units
Emission Limitation Averaging
Period1 TRUE 310 Opacity 0 0.00% 0 0 0 0 0 30 % 6min
1 TRUE 310 Opacity 0 0.00% 0 0 0 0 0 20 % 3hrRA
1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 50 ppm 7dRA
1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 25 ppm 365dRA
1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 106 ppm 7dRA
1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 80 ppm 7dRA
1 TRUE 310 CO 0 0.00% 0 0 0 0 0 500 ppm hour
1 TRUE 310 H2S 1 0.05% 0 1 0 0 0 162 ppm 3hrRA
1 TRUE 310 H2S 6 0.27% 0 6 0 0 0 162 ppm 3hrRA
1 TRUE 310 H2S 0 0.00% 0 0 0 0 0 162 ppm 3hrRA
1 TRUE 310 H2S 0 0.00% 0 0 0 0 0 162 ppm 3hrRA
1 TRUE 310 H2S 0 0.00% 0 0 0 0 0 60 ppm 365dRA
1 TRUE 310 SO2 138 6.25% 0 0 138 0 0 250 ppm 12hrRA
1 TRUE 310 SO2 445 20.15% 0 0 437 8 0 250 ppm 12hrRA
1 310 0 0 0 0 0 0 0 0 0
Point Source
SRU Tailgas Incinerator 2
0
SRU Tailgas Incinerator 2
Boiler #7
FCC Regenerator Vent
Flare #1
Flare #2
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
0
SRU Tailgas Incinerator 1
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Fuel Gas Mix Point
Fuel Gas Mix Point
Flare #2
Flare #3
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
Chevron Products Co.
0
Boiler #7
Boiler #7
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Flare #1
Flare #1
Flare #2
FCC Regenerator Vent
FCC Regenerator Vent
Flare #1
Flare #2
Flare #3
FCC Regenerator Vent
FCC Regenerator Vent
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
0
Chevron Refinery EER 4Q2024
1 Type Code 300 (CMS
Performance Summary) Type Code Channel
Point Source Operating
Hours
Downtime - % of Total Operating Hours
Total CMS
Downtime
RC 721 Hours - Monitor Malfunction
RC 722 Hours - Non-monitor Malfunction
RC 723 Hours -
QA Calibrations
RC 724 Hours - Other Known Causes
RC 725
Hours -
Unknown
Causes1 TRUE 300 NOx 2208 1.38% 30.5 29.25 0 0 1.25 0
1 TRUE 300 O2 2208 1.38% 30.5 29.25 0 0 1.25 0
1 TRUE 300 Opacity 2208 0.07% 1.5 0 0 0 1.5 0
1 TRUE 300 CO 2208 4.09% 90.25 40.25 0.5 47 2.5 0
1 TRUE 300 NOx 2208 4.09% 90.25 40.25 0.5 47 2.5 0
1 TRUE 300 SO2 2208 4.26% 94 44 0.5 47 2.5 0
1 TRUE 300 CO2 2208 4.09% 90.25 40.25 0.5 47 2.5 0
1 TRUE 300 O2 2208 4.09% 90.25 40.25 0.5 47 2.5 0
1 TRUE 300 H2S 2208 1.59% 35 9.5 0 22.75 2.75 0
1 TRUE 300 TRS 2208 1.98% 43.75 26.5 14.75 0 2.5 0
1 TRUE 300 H2S 2208 1.06% 23.5 0 0 23 0.5 0
1 TRUE 300 TRS 2208 1.36% 30 0 29.5 0 0.5 0
1 TRUE 300 H2S 2208 1.28% 28.25 3 0 24.75 0.5 0
1 TRUE 300 TRS 2208 2.75% 60.75 35.25 0 0 25.5 0
1 TRUE 300 H2S 2208 1.79% 39.5 0 0 39 0.5 0
1 TRUE 300 SO2 2208 0.07% 1.5 0.25 0 0 1.25 0
1 TRUE 300 O2 2208 0.07% 1.5 0.25 0 0 1.25 0
1 TRUE 300 SO2 2208 2.22% 49 48 0 0 1 0
1 TRUE 300 O2 2208 2.22% 49 48 0 0 1 0
1 300 0 0 0 0 0 0
1 Type Code 250
(Performance Specification
RATA Results)
Type Code Channel
Date of Most Current
RATA
Date of Preceding
RATA
Months Between
RATA's
Units of
Measurement CEM Value Reference Method
Value
Relative
accuracy Pass/ Fail
1 377 Days 250 NOx 08/27/24 08/16/23 12 ppm 0.081 0.072 0.01% P
1 377 Days 250 O2 08/27/24 08/16/23 12 0 3.8 3.8 1.80% P
1 378 Days 250 SO2 08/26/24 08/14/23 12 ppm 5.6 1.5 9.02% P
1 378 Days 250 NOx 08/26/24 08/14/23 12 ppm 9.6 1.5 1.24% P
1 378 Days 250 CO 08/26/24 08/14/23 12 ppm 95.4 93.5 0.62% P
1 378 Days 250 CO2 08/26/24 08/14/23 12 ppm 17.7 18 1.94% P
1 378 Days 250 O2 08/26/24 08/14/23 12 0 2 2 1.79% P
1 0 Days 250 H2S 09/21/20 09/21/20 12 ppm 8.9 5.81 3.30% P
1 0 Days 250 H2S 09/22/20 09/22/20 12 ppm 8.29 5.39 2.93% P
1 362 Days 250 H2S 08/20/24 08/24/23 12 ppm 0 0.07 0.10% P
1 360 Days 250 H2S 08/19/24 08/25/23 12 ppm 0.12 0.1 0.16% P
1 372 Days 250 SO2 08/21/24 08/15/23 12 ppm 65.1 74.1 13.66% P
1 372 Days 250 SO2 08/21/24 08/15/23 12 lb./hr. 1.5 1.7 15.74% P
1 372 Days 250 O2 08/21/24 08/15/23 12 0 3.7 3.8 1.33% P
1 367 Days 250 SO2 08/22/24 08/21/23 12 ppm 139.1 165.2 18.03% P
1 367 Days 250 SO2 08/22/24 08/21/23 12 lb./hr. 2.2 3.3 5.41% P
1 367 Days 250 O2 08/22/24 08/21/23 12 0 8.4 8.4 1.21% P
1 0 Days 250 0 01/00/00 01/00/00 0 0 0 0 0.00% 0
1 Type Code 260(CGA Results)Type Code Channel Date Audit Point No. Cylinder ID
Cylinder Expiration
Date
Type of
Certification
Units of
Measurement CEM Value Cylinder
Value
Precision
%Pass/ Fail Range - High or
Low1 Valid Cal. Gas 260 NOx 11/06/24 1 CC63048 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 136.1 135.4 49.00% P Low
1 Valid Cal. Gas 260 NOx 11/06/24 2 CC3688 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 279 276.1 105.00% P High
1 Valid Cal. Gas 260 O2 11/06/24 1 EB0027762 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 5.1 5 60.00% P High
1 Valid Cal. Gas 260 O2 11/06/24 2 CC316355 05/01/26 EPA Traceability Protocol (Sept. 1997)ppm 8.1 8 75.00% P High
1 Valid Cal. Gas 260 CO 11/07/24 1 CC96320 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 247.1 249.9 -113.00% P Low
1 Valid Cal. Gas 260 CO 11/07/24 2 EB0157339 08/02/31 EPA Traceability Protocol (Sept. 1997)ppm 543.7 552.2 -154.00% P High
1 Valid Cal. Gas 260 CO2 11/07/24 1 CC200802 03/20/31 EPA Traceability Protocol (Sept. 1997)ppm 6.4 6.5 -184.00% P Low
1 Valid Cal. Gas 260 CO2 11/07/24 2 CC487479 03/02/31 EPA Traceability Protocol (Sept. 1997)ppm 13.9 14 -79.00% P High
1 Valid Cal. Gas 260 NOx 11/07/24 1 CC320573 01/03/31 EPA Traceability Protocol (Sept. 1997)ppm 56.3 55.5 151.00% P Low
1 Valid Cal. Gas 260 NOx 11/07/24 2 CC262317 05/23/30 EPA Traceability Protocol (Sept. 1997)ppm 111.4 111.1 27.00% P High
1 Valid Cal. Gas 260 O2 11/08/24 1 EB0123082 05/31/31 EPA Traceability Protocol (Sept. 1997)% 5.1 5 220.00% P Low
1 Valid Cal. Gas 260 O2 11/08/24 2 EB0141908 05/31/31 EPA Traceability Protocol (Sept. 1997)% 8 8.1 -25.00% P High
1 Valid Cal. Gas 260 SO2 11/07/24 1 CC733445 08/22/30 EPA Traceability Protocol (Sept. 1997)ppm 55.6 55.08 89.00% P Low
1 Valid Cal. Gas 260 SO2 11/07/24 2 SG912106BAL 08/29/30 EPA Traceability Protocol (Sept. 1997)ppm 110.6 110.3 30.00% P High
1 Valid Cal. Gas 260 H2S 11/05/24 1 CC160176 04/04/27 EPA PROTOCOL II GASppm 63.8 71.44 -1069.00% P Low
1 Valid Cal. Gas 260 H2S 11/5/24 2 CC18776 10/19/26 EPA PROTOCOL II GASppm 153 159 -4 P High
1 Valid Cal. Gas 260 TRS 11/5/24 1 CC97784 12/16/24 EPA PROTOCOL II GASppm 12,122 12,526 -3 P Low
1 Valid Cal. Gas 260 TRS 11/5/24 2 EB0140133 9/21/25 EPA PROTOCOL II GASppm 26,059 27,571 -5 P High
1 Valid Cal. Gas 260 H2S 11/7/24 1 ALM040013 6/30/26 EPA PROTOCOL II GASppm 70 70 0 P Low
1 Valid Cal. Gas 260 H2S 11/7/24 2 CC906612 6/9/26 EPA PROTOCOL II GASppm 157 159 -1 P High
1 Valid Cal. Gas 260 TRS 11/7/24 1 CC341983 12/4/26 EPA PROTOCOL II GASppm 12,756 12,657 1 P Low
1 Valid Cal. Gas 260 TRS 11/7/24 2 EB0156491 9/23/27 EPA PROTOCOL II GASppm 27,672 27,582 0 P High
1 Valid Cal. Gas 260 H2S 12/12/24 1 CC148981 5/28/26 EPA PROTOCOL II GASppm 66 70 -6 P Low
1 Valid Cal. Gas 260 H2S 12/12/24 2 CC475553 4/8/27 EPA PROTOCOL II GASppm 141 163 -14 P High
1 Valid Cal. Gas 260 TRS 12/12/24 1 CC231302 4/26/25 EPA PROTOCOL II GASppm 2,779 2,491 12 P Low
1 Valid Cal. Gas 260 TRS 12/12/24 2 CC260070 4/12/25 EPA PROTOCOL II GASppm 6,100 5,553 10 P High
1 Valid Cal. Gas 260 H2S 11/6/24 1 ALM044045 3/8/27 EPA Traceability Protocol (Sept. 1997)ppm 68 71 -5 P Low
1 Valid Cal. Gas 260 H2S 11/6/24 2 CC429272 4/5/27 EPA Traceability Protocol (Sept. 1997)ppm 166 162 3 P High
1 Valid Cal. Gas 260 O2 11/4/24 1 ALM054666 4/26/27 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -2 P Low
1 Valid Cal. Gas 260 O2 11/4/24 2 ALM020453 12/12/30 EPA Traceability Protocol (Sept. 1997)ppm 8 8 -2 P High
1 Valid Cal. Gas 260 SO2 11/4/24 1 CC107467 8/29/30 EPA Traceability Protocol (Sept. 1997)ppm 126 126 0 P Low
1 Valid Cal. Gas 260 SO2 11/4/24 2 EB0134129 11/22/29 EPA Traceability Protocol (Sept. 1997)ppm 256 252 2 P High
1 Valid Cal. Gas 260 O2 11/5/24 1 EB0105270 5/31/30 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -3 P Low
1 Valid Cal. Gas 260 O2 11/5/24 2 CC741651 8/23/29 EPA Traceability Protocol (Sept. 1997)ppm 8 8 -1 P High
1 Valid Cal. Gas 260 SO2 11/5/24 1 CC356043 11/1/30 EPA Traceability Protocol (Sept. 1997)ppm 117 123 -5 P Low
1 Valid Cal. Gas 260 SO2 11/5/24 2 ALM047181 2/1/27 EPA Traceability Protocol (Sept. 1997)ppm 238 250 -5 P High
1 260 0 1/0/00 0 0 1/0/00 0 0 0 0 0 0 0
1 Type Code 270(Linearity Test Results)Type Code Channel Date Audit Point No. Cylinder ID
Cylinder Expiration
Date
Type of
Certification
Units of
Measurement CEM Value Cylinder
Value
Precision
%Pass/ Fail Range - High or
Low
1 270 0 01/00/00 0 0 01/00/00 0 0 0 0 0.00% 0 0
Point Source
Point Source
Point Source
Point Source
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Flare #1
Flare #1
Flare #1
Flare #2
SRU Tailgas Incinerator 2
FCC Regenerator Vent
Flare #1
Flare #2
Flare #3
Fuel Gas Mix Point
Boiler #7
Boiler #7
SRU Tailgas Incinerator 2
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Boiler #7
Boiler #7
FCC Regenerator Vent
Flare #3
Flare #1
Flare #1
Flare #2
Flare #2
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
0
Boiler #7
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Boiler #7
0
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
0
Flare #3
Flare #3
Fuel Gas Mix Point
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
Boiler #7
Boiler #7
Flare #3
Flare #3
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Flare #2
Flare #2
Flare #2
Flare #1
0
Chevron Refinery EER 4Q2024
1 Type Code 210
(Pollutant Concentration
Exceeded Span of CEM)
Type Code Channel Start Date Start Time End Date End Time Hours
1 139 210 H2S 10/18/24 4:02 10/18/24 4:11 0.15
1 139 210 H2S 10/18/24 4:27 10/18/24 4:37 0.17
1 278 210 H2S 10/18/24 4:54 10/18/24 5:40 0.77
1 TRUE 210 H2S 10/7/24 15:25 10/7/24 15:29 0.07
1 210 H2S 10/18/24 3:47 10/18/24 3:51 0.07
1 210 H2S 10/18/24 3:58 10/18/24 4:02 0.07
1 210 H2S 10/18/24 4:09 10/18/24 4:13 0.07
1 210 H2S 10/18/24 4:17 10/18/24 4:29 0.20
1 210 H2S 10/18/24 4:36 10/18/24 4:40 0.07
1 210 H2S 10/18/24 4:42 10/18/24 4:47 0.08
1 210 H2S 10/18/24 4:51 10/18/24 5:18 0.45
1 210 H2S 11/7/24 14:48 11/7/24 14:53 0.08
1 210 H2S 11/18/24 2:45 11/18/24 2:56 0.18
1 210 H2S 11/18/24 3:00 11/18/24 3:04 0.07
1 210 H2S 11/18/24 3:07 11/18/24 3:22 0.25
1 210 H2S 11/18/24 3:26 11/18/24 3:33 0.12
1 210 H2S 11/18/24 3:40 11/18/24 3:55 0.25
1 210 H2S 11/18/24 4:15 11/18/24 4:22 0.12
1 210 H2S 11/18/24 4:29 11/18/24 4:33 0.07
1 210 H2S 11/18/24 4:41 11/18/24 5:10 0.48
1 210 H2S 11/18/24 5:15 11/18/24 5:33 0.30
1 210 H2S 11/18/24 5:37 11/18/24 5:44 0.12
1 210 H2S 11/18/24 5:48 11/18/24 5:59 0.18
1 210 H2S 11/18/24 6:04 11/18/24 6:22 0.30
1 210 H2S 11/18/24 6:26 11/18/24 6:52 0.43
1 210 H2S 11/18/24 6:59 11/18/24 7:26 0.45
1 210 H2S 11/18/24 7:37 11/18/24 8:00 0.38
1 210 H2S 11/18/24 8:22 11/18/24 8:38 0.27
1 210 H2S 11/18/24 8:45 11/18/24 9:07 0.37
1 210 H2S 11/18/24 9:10 11/18/24 9:22 0.20
1 210 H2S 11/26/24 7:33 11/26/24 7:41 0.13
1 210 H2S 10/2/24 8:45 10/2/24 8:49 0.07
1 210 H2S 10/2/24 8:58 10/2/24 9:06 0.13
1 210 H2S 10/30/24 19:42 10/30/24 19:59 0.28
1 210 H2S 10/31/24 1:48 10/31/24 2:09 0.35
1 210 SO2 10/1/24 10:57 10/1/24 11:13 0.27
1 210 SO2 10/1/24 11:27 10/1/24 11:42 0.25
1 210 SO2 12/26/24 1:17 12/26/24 22:03 20.77
1 210 SO2 12/26/24 22:57 12/27/24 0:53 1.93
1 210 SO2 12/27/24 2:34 12/27/24 2:37 0.05
1 210 SO2 12/27/24 2:42 12/27/24 3:45 1.05
1 210 SO2 12/27/24 3:47 12/27/24 4:03 0.27
1 210 SO2 12/27/24 5:56 12/27/24 6:15 0.32
1 210 SO2 12/27/24 6:17 12/27/24 6:24 0.12
1 210 SO2 12/27/24 6:40 12/30/24 16:49 82.15
1 210 SO2 12/30/24 16:55 12/31/24 4:27 11.53
1 210 SO2 12/31/24 4:57 12/31/24 5:08 0.18
1 210 SO2 12/31/24 5:47 12/31/24 6:20 0.55
1 210 SO2 12/31/24 6:28 12/31/24 6:56 0.47
1 210 SO2 12/31/24 7:13 12/31/24 9:00 1.78
1 210 SO2 12/31/24 9:25 12/31/24 12:23 2.97
1 210 SO2 12/31/24 12:26 12/31/24 12:32 0.10
1 210 SO2 12/31/24 16:11 12/31/24 16:16 0.08
1 210 SO2 12/31/24 18:07 12/31/24 20:13 2.10
1 210 SO2 10/1/24 10:46 10/1/24 10:57 0.18
1 210 SO2 11/2/24 16:01 11/2/24 16:05 0.07
1 210 SO2 11/9/24 13:18 11/9/24 13:23 0.08
1 210 SO2 11/9/24 13:31 11/9/24 13:35 0.07
1 210 SO2 12/5/24 21:51 12/5/24 23:15 1.40
1 210 SO2 12/7/24 9:59 12/7/24 10:03 0.07
1 210 SO2 12/7/24 10:05 12/7/24 10:39 0.57
1 210 SO2 12/9/24 1:15 12/9/24 1:23 0.13
1 210 SO2 12/9/24 11:34 12/9/24 12:06 0.53
1 210 SO2 12/9/24 12:06 12/9/24 12:24 0.30
1 210 SO2 12/23/24 15:30 12/23/24 16:11 0.68
1 210 SO2 12/28/24 3:38 12/28/24 3:42 0.07
1 210 SO2 12/30/24 6:17 12/30/24 6:21 0.07
1 210 SO2 12/31/24 16:29 12/31/24 16:35 0.10
1 210 0 1/0/00 0:00 1/0/00 0:00
1
1 Yes
1 139.13 TC 220 Hours 879.25 TC 220 Hours 0.00 TC 230 Hours 0.00 Events 0.00 Hours 0.00 Events 0.00 0.00
1 879.25 TC 300 Hours 0.00 TRUE
None Reported None Reported None Reported None Reported None Reported None Reported
Point Source
Yes
Flare #2
Flare #2
Type Code 550(Changes in Operation in
Control Equipment When
CEM Data Not Available)
Type Code 500
(Boiler Operating Daysw/o 18 Hours of Data)
Type Code 450
(Data Excluded)
Type Code 210
(Pollutant ConcentrationExceeded Span of CEM)
Type Code 220
(Monitor OutageDuring Point Source Operation)
Type Code 230(Manual Sample - Alternate
Sampling During Monitor
Outage)
Type Code 240
(CEM Modifications)
Type Code 530
(Excess Emissions During Emergency Conditions)
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #1
Flare #1
Flare #1
Flare #2
Flare #2
Flare #2
Flare #3
Flare #3
Flare #3
Flare #3
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
0
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
Chevron Refinery EER 4Q2024
Relative Accuracy Overview
Point Source Channel
Date of Most
Current
RATA
Date of
Preceding
RATA
Months Between
RATA's
Units
Measured CEM Value Reference Method
Value
Relative
Accuracy Pass/ Fail
Boiler #7 NOx 08/27/24 08/16/23 12 ppm 0.081 0.07 0.01% P
Boiler #7 O2 08/27/24 08/16/23 12 3.8 3.80 1.80% P
FCC Regenerator Vent SO2 08/26/24 08/14/23 12 ppm 5.6 1.50 9.02% P
FCC Regenerator Vent NOx 08/26/24 08/14/23 12 ppm 9.6 1.50 1.24% P
FCC Regenerator Vent CO 08/26/24 08/14/23 12 ppm 95.4 93.50 0.62% P
FCC Regenerator Vent CO2 08/26/24 08/14/23 12 ppm 17.7 18.00 1.94% P
FCC Regenerator Vent O2 08/26/24 08/14/23 12 2 2.00 1.79% P
Flare #1 H2S 09/21/20 09/21/20 12 ppm 8.9 5.81 3.30% P
Flare #2 H2S 09/22/20 09/22/20 12 ppm 8.29 5.39 2.93% P
Flare #3 H2S 08/20/24 08/24/23 12 ppm 0 0.07 0.10% P
Fuel Gas Mix Point H2S 08/19/24 08/25/23 12 ppm 0.12 0.10 0.16% P
SRU Tailgas Incinerator 1 SO2 08/21/24 08/15/23 12 ppm 65.1 74.10 13.66% P
SRU Tailgas Incinerator 1 SO2 08/21/24 08/15/23 12 lb./hr. 1.5 1.70 15.74% P
SRU Tailgas Incinerator 1 O2 08/21/24 08/15/23 12 3.7 3.80 1.33% P
SRU Tailgas Incinerator 2 SO2 08/22/24 08/21/23 12 ppm 139.1 165.20 18.03% P
SRU Tailgas Incinerator 2 SO2 08/22/24 08/21/23 12 lb./hr. 2.2 3.30 5.41% P
SRU Tailgas Incinerator 2 O2 08/22/24 08/21/23 12 8.4 8.40 1.21% P
*
NSPS CGA Fourth 2024
Audit Gas Ranges Audit Gas Ranges
AP1 Low AP2 Low AP1 High AP2 High
Boiler #7 NOx 11/6/24 500 135.4 100 to 150
Boiler #7 NOx 11/6/24 500 276.1 250 to 300
Boiler #7 O2 11/6/24 21 5 4 to 6
Boiler #7 O2 11/6/24 21 8 8 to 12
FCC Regenerator Vent CO 11/7/24 1000 249.9 200 to 300
FCC Regenerator Vent CO 11/7/24 1000 552.2 500 to 600
FCC Regenerator Vent CO2 11/7/24 25 6.5 5 to 8
FCC Regenerator Vent CO2 11/7/24 25 14 10 to 14
FCC Regenerator Vent NOx 11/7/24 200 55.5 40 to 60
FCC Regenerator Vent NOx 11/7/24 200 111.1 100 to 120
FCC Regenerator Vent O2 11/8/24 10 5 4 to 6
FCC Regenerator Vent O2 11/8/24 10 8.1 8 to 12
FCC Regenerator Vent SO2 11/7/24 200 55.08 40 to 60
FCC Regenerator Vent SO2 11/7/24 200 110.3 100 to 120
Flare #1 H2S 11/5/24 300 71.44 60 to 90
Flare #1 H2S 11/5/24 300 159.3 150 to 180
Flare #1 TRS 11/5/24 250000 12526 50000 to 75000
Flare #1 TRS 11/5/24 250000 27571 125000 to 150000
Flare #2 H2S 11/7/24 300 69.7 60 to 90
Flare #2 H2S 11/7/24 300 158.8 150 to 180
Flare #2 TRS 11/7/24 250000 12657 50000 to 75000
Flare #2 TRS 11/7/24 250000 27582 125000 to 150000
Flare #3 H2S 12/12/24 300 70.46 60 to 90
Flare #3 H2S 12/12/24 300 163 150 to 180
Flare #3 TRS 12/12/24 250000 2491 50000 to 75000
Flare #3 TRS 12/12/24 250000 5553 125000 to 150000
Fuel Gas Mix Point H2S 11/6/24 300 70.76 60 to 90
Fuel Gas Mix Point H2S 11/6/24 300 161.6 150 to 180
SRU Tailgas Incinerator 1 O2 11/4/24 21 5.09 4 to 6
SRU Tailgas Incinerator 1 O2 11/4/24 21 8.04 8 to 12
SRU Tailgas Incinerator 1 SO2 11/4/24 500 125.7 100 to 150
SRU Tailgas Incinerator 1 SO2 11/4/24 500 251.6 250 to 300
SRU Tailgas Incinerator 2 O2 11/5/24 21 5.04 4 to 6
SRU Tailgas Incinerator 2 O2 11/5/24 21 7.97 8 to 12
SRU Tailgas Incinerator 2 SO2 11/5/24 500 123.2 100 to 150
SRU Tailgas Incinerator 2 SO2 11/5/24 500 249.5 250 to 300
*
Point Source Channel Audit Date Low Span Audit Gas Used High Span Audit Gas Used
Chevron Refinery EER 4Q2024
Type Code 280 (COMS Attenuator Filters) Procedure 3
Point Source Location
Attenuator
I.D.
Attenuator
Certification Date
Certified Attenuator
Opacity
OPLR,
SECR, or
PLCF,
Corrected Opacity
Value
Range
Low, Mid, & High
Certification
1-year or 5-year
FCC Regenerator Vent Flue Gas
Duct DHT200 /14108330 3/4/24 13 0.8996 21.68
Low 1 Year
FCC Regenerator Vent Flue Gas
Duct DHT200 /14108330 3/4/24 25 0.8996 39.4
Mid 1 Year
FCC Regenerator Vent Flue Gas
Duct DHT200 /14108330 3/4/24 37 0.8996 55.33
High 1 Year
*
Opacity Monitor Response (Average of 5)
Low Range Mid Range High Range
FCC Regenerator Vent Flue Gas
Duct 11/6/24 7 0.790 0.790 0.005 1.297
FCC Regenerator Vent Flue Gas
Duct 11/6/24 7 0.450 0.450 0.004 0.877
FCC Regenerator Vent Flue Gas
Duct 11/6/24 7 0.170 0.170 0.006 0.735
Point
Source Location Audit Date Mean Difference Standard Deviation
Confidence
Coefficient
Calibration
Error (≤ 3%)
Type Code 281 (Procedure 3 - COMS Filter Audit Calibration Error)
Chevron Refinery EER 4Q2024
Monitoring Information TC 210, 230, & 240
Type Code 210
(Pollutant Concentration Exceeded Span of CEM) - 500 (All)
*
Sum of Hours Column Labels
Row Labels (blank) H2S SO2 Grand Total
(blank)0 0
Flare #1 1.23 1.23
Flare #2 5.82 5.82
Flare #3 0.83 0.83
SRU Tailgas Incinerator 1 126.93 126.93
SRU Tailgas Incinerator 2 4.32 4.32
Grand Total 0 7.88 131.25 139.13
*
Type Code 230
(Manual Sample - Alternate Sampling During Monitor Outage) - 500 (All)
*
Sum of Hours Column Labels
Row Labels (blank) Grand Total
(blank)0 0
Grand Total 0 0
*
Type Code 240
(CEM Modifications) - 100 (All)
*
Count of Channel Column Labels
Row Labels (blank) Grand Total
(blank)
(blank)
Grand Total
Chevron Refinery EER 4Q2024
Type Code 220
(Monitor Outage During Point Source Operation) - 600 (All)
*
Sum of Hours Column Labels
Row Labels (blank)724 723 721 722 Grand Total
(blank)
(blank)
0 0
FCC Regenerator Vent
Opacity
Quarterly Audit 1.5 1.5
CO
Quarterly Audit 2.5 2.5
Daily Validation 46 46
Service sample system, replaced ammonia scrubbers for PM. 1 1
Misc. Cal Drift, calibrated and revalidated. 1 1
SO2 Calidation drifted. Technician responded quickly and checked
sample system flow, temperature and pressure. Recalibrated and
revalidated.
1.5 1.5
During weekly PM, found broken plastic washer on H2S cal gas and
replaced. Revalidated. No further issues. 0.5 0.5
Calibration Drift. Sample system failed. Analyzer responded quickly.
Thermocouple card was pulled loose. Analyzer team rebuilt sample box
and replaced Dryer, scrubber and filters. Recalibrated and revalidated.
37.75 37.75
CO2
Quarterly Audit 2.5 2.5
Daily Validation 46 46
Service sample system, replaced ammonia scrubbers for PM. 1 1
Misc. Cal Drift, calibrated and revalidated. 1 1
SO2 Calidation drifted. Technician responded quickly and checked
sample system flow, temperature and pressure. Recalibrated and
revalidated.
1.5 1.5
During weekly PM, found broken plastic washer on H2S cal gas and
replaced. Revalidated. No further issues. 0.5 0.5
Calibration Drift. Sample system failed. Analyzer responded quickly.
Thermocouple card was pulled loose. Analyzer team rebuilt sample box
and replaced Dryer, scrubber and filters. Recalibrated and revalidated.
37.75 37.75
NOx
Quarterly Audit 2.5 2.5
Daily Validation 46 46
Service sample system, replaced ammonia scrubbers for PM. 1 1
Misc. Cal Drift, calibrated and revalidated. 1 1
SO2 Calidation drifted. Technician responded quickly and checked
sample system flow, temperature and pressure. Recalibrated and
revalidated.
1.5 1.5
During weekly PM, found broken plastic washer on H2S cal gas and
replaced. Revalidated. No further issues. 0.5 0.5
Calibration Drift. Sample system failed. Analyzer responded quickly.
Thermocouple card was pulled loose. Analyzer team rebuilt sample box
and replaced Dryer, scrubber and filters. Recalibrated and revalidated.
37.75 37.75
SO2
Quarterly Audit 2.5 2.5
Daily Validation 46 46
Service sample system, replaced ammonia scrubbers for PM. 1 1
Misc. Cal Drift, calibrated and revalidated. 1 1
SO2 Calidation drifted. Technician responded quickly and checked
sample system flow, temperature and pressure. Recalibrated and
revalidated.
5.25 5.25
During weekly PM, found broken plastic washer on H2S cal gas and
replaced. Revalidated. No further issues. 0.5 0.5
Calibration Drift. Sample system failed. Analyzer responded quickly.
Thermocouple card was pulled loose. Analyzer team rebuilt sample box
and replaced Dryer, scrubber and filters. Recalibrated and revalidated.
37.75 37.75
O2
Quarterly Audit 2.5 2.5
Daily Validation 46 46
Service sample system, replaced ammonia scrubbers for PM. 1 1
Misc. Cal Drift, calibrated and revalidated. 1 1
SO2 Calidation drifted. Technician responded quickly and checked
sample system flow, temperature and pressure. Recalibrated and
revalidated.
1.5 1.5
During weekly PM, found broken plastic washer on H2S cal gas and
replaced. Revalidated. No further issues. 0.5 0.5
Calibration Drift. Sample system failed. Analyzer responded quickly.
Thermocouple card was pulled loose. Analyzer team rebuilt sample box
and replaced Dryer, scrubber and filters. Recalibrated and revalidated.
37.75 37.75
Flare #1
H2S
Quarterly Audit 2.75 2.75
Daily Validation 22.75 22.75
Misc. Cal Drift, calibrated and revalidated. 0.75 0.75
Analyzer went into a fault status, however it passed the next validation
and the fault cleared. No further issues. 8.75 8.75
Chevron Refinery EER 4Q2024
Sum of Hours Column Labels
Row Labels (blank)724 723 721 722 Grand Total
TRS
Quarterly Audit 2.5 2.5
A power outage occurred during a shutdown. This caused the shelter
temperature to drop and the analyzer to go into back purge mode.
After power was restored, the analyzer warmed back up, began to
sample and passed the next validation.
14.75 14.75
Calibration drift. Analyzer went into fault status intermittantly during
validation. Analyzer was calibrated and revalidated. No further issue.
26.5 26.5
Flare #2
H2S
Quarterly Audit 0.5 0.5
Daily Validation 23 23
TRS
Quarterly Audit 0.5 0.5
Calibration drift. A power outage occurred during a shutdown. This
caused multiple systems to experience issues that were not
immediately noticed. Once technicians were aware, they quicklly
responded recalibrated and revalidated.
29.5 29.5
Flare #3
H2S
Quarterly Audit 0.5 0.5
Daily Validation 24.75 24.75
Misc. Cal Drift, calibrated and revalidated. 3 3
TRS
Quarterly Audit 3.75 3.75
Analyzer was inadvertantly left in Maintenance mode. Once the cal
drift alarm came in the next moring, technicians ran the daily validation
and left analyzer in run mode.
21.75 21.75
Calibration Drift. Bypass flow dropped and required adjustment.
Technician then recalibrated and revalidated. 35.25 35.25
Fuel Gas Mix Point
H2S
Quarterly Audit 0.5 0.5
Daily Validation 39 39
SRU Tailgas Incinerator 1
SO2
Quarterly Audit 1.25 1.25
Misc. Cal Drift, calibrated and revalidated. 0.25 0.25
O2
Quarterly Audit 1.25 1.25
Misc. Cal Drift, calibrated and revalidated. 0.25 0.25
SRU Tailgas Incinerator 2
SO2
Quarterly Audit 1 1
Misc. Cal Drift, calibrated and revalidated. 0.25 0.25
Calibration drift. Analyzer signal froze due to SD memory card issue.
Analyzer team quickly responded and were able to perform a hard
reset on the analyzer then perform a calibration and revalidation.
19.75 19.75
Calibration drift. Technician quickly responded to callout. Found the
sample system moisture alarm was on. This stopped the sample pump.
Technician cleaned moisture carryover issue which turned on the
pump. Recalibrated and revalidated.
28 28
O2
Quarterly Audit 1 1
Misc. Cal Drift, calibrated and revalidated. 0.25 0.25
Calibration drift. Analyzer signal froze due to SD memory card issue.
Analyzer team quickly responded and were able to perform a hard
reset on the analyzer then perform a calibration and revalidation.
19.75 19.75
Calibration drift. Technician quickly responded to callout. Found the
sample system moisture alarm was on. This stopped the sample pump.
Technician cleaned moisture carryover issue which turned on the
pump. Recalibrated and revalidated.
28 28
Boiler #7
NOx
Quarterly Audit 1.25 1.25
Misc. Cal Drift, calibrated and revalidated. 1.25 1.25
Calibration drift. Technician found wet sample system filters. Replaced
with dry filters. Recalibrated and revalidated. 1.25 1.25
Calibration drift. Technician found sample system in alarm. "Water
Carry Over" alarm. Technician replaced moisture sensor and cleaned
out resid cup. Replaced genie filter. Recalibrated and revalidated.
26.75 26.75
O2
Quarterly Audit 1.25 1.25
Misc. Cal Drift, calibrated and revalidated. 1.25 1.25
Calibration drift. Technician found wet sample system filters. Replaced
with dry filters. Recalibrated and revalidated. 1.25 1.25
Calibration drift. Technician found sample system in alarm. "Water
Carry Over" alarm. Technician replaced moisture sensor and cleaned
out resid cup. Replaced genie filter. Recalibrated and revalidated.
26.75 26.75
Grand Total 0 53.75 344.5 434.25 46.75 879.25
Chevron Refinery EER 4Q2024
Opy *
Opy Count of Magnitude of Emissions Column Labels
Opy Row Labels Grand Total
Opy Grand Total
SO2 *
SO2 Type Code 410 (SO2) - 6000 (All)
SO2 *
SO2 Count of Magnitude of Emissions Column Labels
SO2 Row Labels 703 704 Grand Total
SO2
A leak was discovered in the SRU that required the unit to be
placed in hot standby in order for operations to locate and repair
the leak. During the course of time operations worked diligently
following safety procedures to locate and repair the leak. This 12
hour SO2 exceedance continued into 2025 as they continued to
follow procedures to find and repair the leak.
SO2 SRU Tailgas Incinerator 1 138 138
SO2
During maintenance and shutdown of the coker unit, SRU2
experienced lowered acid gas feed rates. With ongoing
maintenance of the Coker process unit of uncertain duration, the
refinery placed SRU2 in warm standby mode which caused an
exceedance for our SO2 limit. Of note, the SRU2 was not recieving
sulfur containing process gasses. Once the refinery approached
normal operating conditions after the coker was brought online,
the SRU2 was able to return to regular operating conditions as well
which eliminated the exceedance.
SO2 SRU Tailgas Incinerator 2 437 437
SO2
The Amine #2 unit experienced variable temperature and pressure.
This resulted in inconsistant acid gas feed to the SRU2 unit. In
addition, the final sulfur trap opened and did not reseat properly,
allowing vapor breakthrough of acid gas to the vapor pit and
incinerator. These events led to an SO2 exceedance at the SRU2.
Operations and maintenance teams worked to reseat the sulfur
trap and stabilize the Amine #2. This exceedeance continued into
2025.
SO2 SRU Tailgas Incinerator 2 8 8
SO2 Grand Total 575 8 583
NOx *
NOx Type Code 420 (NOx) - 6000 (All)
NOx *
NOx Count of Magnitude of Emissions Column Labels
NOx Row Labels Grand Total
NOx Grand Total
Chevron Refinery EER 4Q2024
H2S/TRS *
H2S/TRS Type Code 430
(H2S) - 6000 (All)
H2S/TRS *
H2S/TRS Count of Magnitude of Emissions Column Labels
H2S/TRS Row Labels 702 Grand Total
H2S/TRS Flare #1
H2S/TRS
VGO unit temporarily paused operation due to the feed pump
spillback going open which caused Flare 1 to temporarily exceed
the H2S limit. During a cold weather front, feed became prone to
slightly "waxing up" which caused an innacurate flow reading.
Operations followed refinery procedures, placed the valve in
manual and added steam hose for heat to continue to run the unit.
Shortly after the event, our meter began to read correctly. The
refinery has an MOC in place to adjust logic so that if the meter
waxes up, we can continue to run without exceeding
environmental limits.
1 1
H2S/TRS Flare #2
H2S/TRS
The HDS temporarily paused operation due to attempts to bring
K10 compressor on-line. During the attempted start-up, the 1st
stage RV lifted, routing excess H2S to the Flare #2. The H2S
breached water seals causing an H2S exceedance. Operations
followed written procedures to start up the K11 compressor
instead, while the K10 compressor was repaired. This eliminated
the H2S exceedance.
6 6
H2S/TRS Grand Total 7 7
CO *
CO Type Code 440
(CO) - 6000 (All)
CO *
CO Count of Magnitude of Emissions Column Labels
CO Row Labels Grand Total
CO Grand Total
VOC/THC *
VOC/THC Type Code 460 (VOC/THC) - 6000 (All)
VOC/THC *
VOC/THC Count of Magnitude of Emissions Column Labels
VOC/THC Row Labels Grand Total
VOC/THC Grand Total
O2 *
O2 Type Code 470
(TRS as O2) - 6000 (All)
O2 *
O2 Count of Magnitude of Emissions Column Labels
O2 Row Labels Grand Total
O2 Grand Total
Chevron Refinery EER 4Q2024
Type Code 500
Before February 28, 2005 (Boiler Operating Days w/o 18 Hours of
Data) After February 28, 2005 (90% Operating Hours For each 30 BOD)
- 500
(All)
*
Count of Channel Column Labels
Row Labels Grand Total
Grand Total
*
Type Code 510
(F-factor, Equations & Conversion Factors) - 500 (All)
Count of F-factor Column Labels
Row Labels Grand Total
Grand Total
*
Type Code 520
(Minimum Data Not
Obtained <22/30 BODs) - 500
(All)
Count of Channel Column Labels
Row Labels Grand Total
Grand Total
*
Type Code 530
(Excess Emissions During Emergency Conditions) - 500 (All)
Count of Date Column Labels
Row Labels Grand Total
Grand Total
*
Type Code 540
(Fuel Pre-treatment Credit SO2) - 500 (All)
Count of Date Column Labels
Row Labels Grand Total
Grand Total
*
TypeCode 550
(Changes in Operation in Control Equipment When CEM Data Not
Available) - 500
(All)
Column Labels
Row Labels Grand Total
Grand Total