DAQ-2025-002610

1
DAQC-499-25
Site ID 10119 (B5)

MEMORANDUM

TO: FILE – CHEVRON PRODUCTS COMPANY

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Rob Leishman, Environmental Scientist

DATE: May 21, 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: May 21, 2025

SOURCE LOCATION: North Salt Lake/Davis County

SOURCE CONTACT: Tony Pollock – 801-539-7162

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

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:

First Quarter 2025
% 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 2160 NOx 98% 02/04/25 08/27/24
FCC
Regenerator
Vent
Opacity 7.70 30 % - 6min
Boiler #7 2160 O2 98% 02/04/25 08/27/24
FCC
Regenerator
Vent
Opacity 10.00 20 % -
3hrRA

1 8 2

2
First Quarter 2025
% 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
2160 Opacity 100%
FCC
Regenerator
Vent
SO2 0.00
50 ppm -
7dRA at
0%O2
FCC
Regenerator
Vent
2160 CO 96% 02/05/25 08/26/24
FCC
Regenerator
Vent
SO2 0.00
25 ppm -
365dRA at
0% O2
FCC
Regenerator
Vent
2160 NOx 96% 02/05/25 08/26/24
FCC
Regenerator
Vent
NOx 0.00
106 ppm -
7dRA at 0%
O2
FCC
Regenerator
Vent
2160 SO2 96% 02/05/25 08/26/24
FCC
Regenerator
Vent
NOx 0.00
80 ppm -
7dRA at 0%
O2
FCC
Regenerator
Vent
2160 CO2 96% 02/05/25 08/26/24
FCC
Regenerator
Vent
CO 2.00
500 ppm -
1hr
uncorrected
FCC
Regenerator
Vent
2160 O2 96% 02/05/25 08/26/24
FCC
Regenerator
Vent
CO 5.00
500 ppm -
1hr at 0%
O2
Flare #1 2160 H2S 99% 02/06/25 09/21/20 Flare #1 H2S 4.00 162 ppm -
3hrRA
Flare #1 2160 TRS 97% 02/06/25 Flare #2 H2S 12.00 162 ppm -
3hrRA
Flare #2 2160 H2S 96% 02/06/25 09/22/20 Flare #3 H2S 0.00 162 ppm -
3hrRA
Flare #2 2160 TRS 98% 02/06/25 Fuel Gas
Mix Point H2S 0.00 162 ppm -
3hrRA
Flare #3 2160 H2S 98% 02/18/25 08/20/24 Fuel Gas
Mix Point H2S 0.00 60 ppm -
365dRA
Flare #3 2160 TRS 100% 02/18/25
SRU
Tailgas
Incinerator
1
SO2 549.00
250 ppm -
12hrRA at
0% O2
Fuel Gas
Mix Point 2160 H2S 96% 02/04/25 08/19/24
SRU
Tailgas
Incinerator
2
SO2 107.00
250 ppm -
12hrRA at
0% O2
SRU Tailgas
Incinerator 1 2160 SO2 100% 02/05/25 08/21/24
SRU Tailgas
Incinerator 1 2160 O2 100% 02/05/25 08/21/24
SRU Tailgas
Incinerator 2 2160 SO2 94% 02/06/25 08/22/24
SRU Tailgas
Incinerator 2 2160 O2 94% 02/06/25 08/22/24

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 Opacity 0 7.7 0 0 0 30 % - 6min
FCC Regenerator
Vent Opacity 0 10 0 0 0 20 % - 3hrRA
FCC Regenerator
Vent SO2 0 0 0 0 0 50 ppm - 7dRA at 0%
O2
FCC Regenerator
Vent SO2 0 0 0 0 0 25 ppm - 365dRA at 0%
O2
FCC Regenerator
Vent NOx 0 0 0 0 0 106 ppm - 7dRA at 0%
O2
FCC Regenerator
Vent NOx 0 0 0 0 0 80 ppm - 7dRA at 0%
O2
FCC Regenerator
Vent CO 0 0 0 2 0 500 ppm - 1hr
uncorrected
FCC Regenerator
Vent CO 0 0 0 5 0 500 ppm - 1hr at 0% O2
Flare #1 H2S 0 0 3 1 0 162 ppm - 3hrRA
Flare #2 H2S 0 0 9 3 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 0 549 0 0 250 ppm - 12hrRA at 0%
O2
SRU Tailgas
Incinerator 2 SO2 0 56 51 0 0 250 ppm - 12hrRA at 0%
O2

CMS Performance Summary - Hourly Summary
Point
Source Channel Monitor
Malfunction
Non-monitor
Malfunction
QA
Calibrations
Other
Known
Causes
Unknown
Causes
Boiler #7 NOx 32 0 0 1 0
Boiler #7 O2 32 0 0 1 0
FCC Regenerator Vent Opacity 0 0 0 1 0
FCC Regenerator Vent CO 47 0 45 5 0
FCC Regenerator Vent NOx 47 0 45 5 0
FCC Regenerator Vent SO2 47 0 45 5 0
FCC Regenerator Vent CO2 47 0 45 5 0
FCC Regenerator Vent O2 47 0 45 5 0
Flare #1 H2S 0 0 25 1 0
Flare #1 TRS 54 0 0 2 0
Flare #2 H2S 30 0 51 1 0

4
CMS Performance Summary - Hourly Summary
Point
Source Channel Monitor
Malfunction
Non-monitor
Malfunction
QA
Calibrations
Other
Known
Causes
Unknown
Causes
Flare #2 TRS 46 0 0 2 0
Flare #3 H2S 10 0 23 1 0
Flare #3 TRS 1 0 0 1 0
Fuel Gas Mix Point H2S 37 0 45 1 0
SRU Tailgas Incinerator 1 SO2 2 0 0 8 0
SRU Tailgas Incinerator 1 O2 2 0 0 8 0
SRU Tailgas Incinerator 2 SO2 118 0 0 2 0
SRU Tailgas Incinerator 2 O2 118 0 0 2 0

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 2/5/25 7 -0.170 0.479
FCC Regenerator Vent Flue Gas Duct 2/5/25 7 0.120 0.359
FCC Regenerator Vent Flue Gas Duct 2/5/25 7 0.420 0.624

Pollutant Concentration
Exceeded Span of CEM
Monitor Outage During
Point Source Operation
Alternate
Sampling CEM Modifications
48 Hours 1136 Hours 0 Hours 0 Events

5
SOURCE INSPECTION
SUMMARY EVALUATION: Chevron maintains its CEMS as required in R307-170 and 40 CFR
60.13.

Note: The SRU Tailgas Incinerator 1 monitor read 546 hours of excess
emissions coming from the stack during an unplanned shutdown of the
unit. The monitor was left operating while the SRU Tailgas Incinerator 1
was placed on “warm standby” during the repair of the elemental sulfur
pit. There was little or no flow through the stack during the repairs from
December 23, 2024, through January 22, 2025. However, the monitor,
which is upstream of the incinerator, was reading ambient SO2 in the
stack during that time. SRU Tailgas Incinerator 2 stack experienced
excess emissions when a sour water stripper valve froze open releasing
excess steam and water and flooding parts of SRU #2. Additionally, a
detection of H2S in the SRU #2 unit caused a swing in pressure to the
unit causing excess SO2 to the incinerator which was corrected manually
by closing the valve and stopping excess pressure. The refinery does not
have a history of issues causing exceedances similar to the ones
documented above.

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

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
Troy Tortorich Salt Lake Refinery
Refinery Manager Chevron Products Company
685 South Chevron Way
North Salt Lake, UT 84054
Tel [phone]
Fax [phone]
May 15, 2025
CERTIFIED MAIL
RETURN RECEIPT #701806800001 4890 6668
Mr. Bryce Bird, Director
Division of Air Quality
Utah Department of Environmental Quality
195 North 1950 West
P0 Box 144820
Salt Lake City, UT 84114-4820
Vt QUARTER 2025 SRU 1 502 CEM REPORT Supplemental Data
Dear Mr. Bird,
Chevron appreciates the opportunity to provide supplemental information about the Salt Lake Refinery
Sulfur Recovery Unit #1 (SRU 1) sulfur dioxide (SO ) exceedance from January 1,2025, to January 23,
2025 (549 hours) with a detailed maintenance summary and timeline explanation, as requested. This
excess emissions event began on December 26, 2024. Information from before January 1, 2025 was
reported in the 4th Quarter 2024 CEMS report.
Operations personnel in SRU I discovered an elemental sulfur leak on December 23, 2024. SRU I was
placed into warm standby on December 24, 2024. SRU I was placed into warm standby instead of
completely shutting down to mitigate potential sulfur plugging issues in the unit in alignment with operating
and maintaining equipment in a manner consistent with good air pollution control practices.
Initially, it was believed that the issue originated from a flange face located near the sulfur pit. Maintenance
personnel safely removed the steam jacketing and piping in order to inspect the flange. Upon inspection, it
was determined that the flange was not the source of the issue. Upon further investigation on January 2,
2025, it was determined that the leak originated from the concrete in the area where piping penetrates the
SRU I sulfur pit. Chevron obtained a 3 party proposal for the concrete work by January 8th, The repairs
required additional resources and time, which began January 13, 2025.
The concrete was replaced and subsequently required curing time to mitigate cracking. Therefore, SRU 1
remained in warm standby mode until the curing was complete. After completion, Chevron performed
inspections to verif' proper integrity. By January 22, 2025, Maintenance personnel were able to reconnect
the steam jacketing and reinsulate the piping to the pit. SRU I did not process feed at any time during the
maintenance work. Once all work was completed, feed was introduced to the unit which concluded the SO
exceedance.
Work orders to complete the repair are attached to this letter
If you have any additional questions, please contact Tony Pollock at 801-539-7162 or
dItf(2Ichevron.com.
Sincerely,
Troy ortorich
Work Package 289046 Chevron
SRUJ I FITT j REPAIR LEAK AT ENTRANCE OF SULFUR PIT WALL IN TRENCH.
WO Priority i WO CBD 25-Dec-2024 Path SL \ 001 \ 065 \ 065-22 PIPE \ 0065-X005 \ 0065-X005-010 (EQ)
EQ Location 0065-X005-OlO SULFUR FROM SULFUR CONDENSERS TO T65100 SULFUR PiT Asset 2000328872: FIXED EQUIPMENT,PLPING,PROCESS R0002_tb I View Task Details I Salt Lake Refinery
Type RM-RE (Routine Maint \ Reactive Maint)
WCOMP (WO - Waiting Completion)
No I? No
Action
Failure Class PPIP Rolled Up Est Cost $55,811.00
Problem Code Actual Cost to Date $59,904.75 Cause Cost Type MAINT Remedy Cost Object K.DCRSLOO3o5
Eq Breakdown? No
Status History ----
Status Change Date Change By
NEW 23-Dec-2024 BPFQ
PLAN 30-Dec-2024 BYAX
ACTIVE 30-Dec-2024 BYAX
WCOMP 06-May-2025 BPFQ SCD MCD ECD
05-May-2025
Reported By
On Behalf Of
Add't Contact
Petersen, Blake (Operations) Phone# [phone]
Phone #
Description
Long Description
WO Attachments?
SRUI FITT I REPAIR LEAK AT ENTRANCE OF SULFUR PIT WALL IN TRENCH.
Yes (2)
Date Reported 23-Dec-2024
Copyright © 2025 Ron by DLTF i of 2
Company Confidential 14-May-25 09:18
Work Package 289046 Chevron
SRUJ I FITT I REPAIR LEAK AT ENTRANCE OF SULFUR PIT WALL IN TRENCH.
Tasks for Work Order 289046 2 2 i ..L...._.... dwrcnt Status
Task Seq Planner 2 C>rew 2 ih&cjiption 2 <. Status ChangeDate Changefly
00! 0 BYAX TICO SRUI I CLAB Clean out entrance of sulfur pit wall in trench and place sand bags FIN I 3-Jan-2025 PJ-ICX
002 0 NZFO VEaL SRUI I-IPC I Liquid Vac truck support FIN 13-Jan-2025 PHCX
003 0 BYAX TIC SRU I TICD I Bottle watch Repair leak at entrance of sulfur pit wall in trench. FIN 06-Jan-2025 NZFO
004 0 BYAX INSP SRUl INSP Inspect Flange face Repair leak at entrance of sulfir pit wall in trench. FIN 06-Jan-2025 PI-ICX
005 0 BYAX FlrF SRU I FITT F Repair leak at entrance of sulfur pit wall in trench. FIN I 6-Jan-2025 I'HCX
006 0 BPFQ SRUI F INSLF Remove insulation blankets on East end of pipe for inspection FIN 28-Jan-2025 BI'FQ
007 0 BPFQ TSCD SRU IF INSLF Reinstall insulation blankets on East cnd of pipc FIN 30-Jan-2025 TBLN
008 0 BYAX TSFD SRUI F SCAF I Build hootch on the west side of sulfur pit wall and trench. FIN 09-Jan-2025 TBLN
009 0 BYAX SRU IF STRUCTURAL F Repair leak at entrance ofsulfur pit wall in trench. FIN 06-May-2025 BPFQ
010 0 TBLN TSFD SRUt I SCAF I Demo hootch on the west side of sulfur pit wall and trench. FIN 21-Jan-2025 TBLN
Surnmasy\Josts N -- Total .Estirnatesr- $55,81LO0 TolalfActuals $59,904.75 Task DescriptionK < 1 / Lbot Mat'l1 ' Sve< Toolt' Total Labor Marl Svc . Tool Total
289046-00! SRUI I CLAB I Clean out entrance of sulfur pit wall in trench and place 755 0 0 0 755 0 0 0 0 0
sand bags
289046-002 SRL!I I HPC I Liquid Vac truck support 453 0 0 0 453 1998 0 0 1612 3610
289046-003 SRUI I TICD F Bottle watch Repair leak at entrance of sulfur pit 'vail in 378 0 0 0 378 2159 0 0 0 2t59
trench.
289046-004 SRUI I INSP F Inspect Flange face Repair leak at entrance of sulfur pit waIl 378 0 0 0 378 0 0 0 0 0
in trench.
289046-005 SRUI I FITT F Repair leak at entrance ofsulfur pit 'vail in trench. 755 0 0 0 755 3262 0 0 81 3343
289046-006 SRU I I INSLF Remove insulation blankets on East end of pipe for inspection 227 0 0 0 227 0 0 0 0 0
289046-007 SRUI I INSLI Reinstall insulation blankets on East end of pipe 227 0 0 0 227 83 0 0 0 83
289046-008 SRU I I SCAF I Build hootch on the vest side of sulfur pit wail and trench. 1510 0 0 0 1510 615 0 22 0 637
289046-009 SRUI I STRUCTURAL F Repair leak at entrance of sulfur pit wall in trench. 0 0 49620 0 49620 0 0 49620 0 49620
289046-010 SRUI I SCAF I Demo hootch on the west side of sulfur pit wall and trench. 1510 0 0 0 1510 452 0 0 0 452
where parameter: ( exists ((select siteid from siteauth al.groupuser hl,maxgroup ml.applicationauth tl where bl.userid = DLTF and hi .groupnarne=al.groupname and hi .groupnaniemI.groupnanie
and rnl.independent= I and al.groupname= tl.groupname and tl.app = WOTRACK and al.siteid= workorder.siteid ) union all (select siteid from siteauth a,groupuserbmaxgroup m where b.userid
DLTF1 and b.groupname=a.groupname and b.groupnatne=m.groupname and in.independent = 0 and a.siteid = workorder.siteid and (exists (select I from maxgroup m2,applieationzsuth egroupuser d
where d.userid = DLTF and d.groupname = m2.groupname and d.groupname = c.groupnanle and m2.independcnt = 0 and c.app = WOTRACK' ))) )) and ( ( workorder.workorderid = 5492673))
Copyright f3 2025 Run by DLTF 2 of 2
Company Confidential 14-May-25 09:18
Chevron
Troy Tortorich Chevron Products Company
Refinery Manager Salt Lake Refinery
685 South Chevron Way
North Salt Lake, Utah 84054
Tel [phone]
April 28, 2025
CERTIFIED MAIL
RETURN RECEIPT # 7021 2720 0001 4083 5558
Mr. Bryce Bird, Director
Division of Air Quality
Utah Department of Environmental Quality
1St QUARTER 2025 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 I' quarter of 2025. This is in accordance with IJACR 307-170 and applicable 40 CFR 60 subparts
A, J, and Ja requirements. This report contains data on the following monitoring systems:
" Boiler 7 N0x.O2CEM
" FCC regenerator opacity COMS
" FCC regenerator CO. C02 NOx, SO2, and 02 CEM
" Fuel Gas H2S CEM
" Flare I 1-I2S, TRS CEM
" Flare 2 H2S, TRS CEM
" Flare 3 H2S, TRS CEM
" SRU 1S02and02CEM
" SRU2S02and02CEM
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
dltfi2ichevron com.
I certi& 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 F' quarter of 2025.
Sincerely,
Troy Tortorich
Chevron Refinery EER 1Q2025
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
Contact
1 100 Troy Tortorich 01100003 [phone] Tony Pollock
1 100 0 0 0 0
1 Type Code 110
(Point Source Identification)Type Code Point Source
Quarter
1 - 4 Year Point Source
Operating Hrs. in
Quarter
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
1 110 1 2025 2160
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
Location
1 200 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
Period
1 TRUE 310 Opacity 7.7 0.36% 0 7.7 0 0 0 30 % 6min
1 TRUE 310 Opacity 10 0.46% 0 10 0 0 0 20 % 3hrRA
1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 50 ppm 7dRA_at_0%O2
1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 25 ppm 365dRA_at_0%O2
1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 106 ppm 7dRA_at_0%O2
1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 80 ppm 7dRA_at_0%O2
1 TRUE 310 CO 2 0.09% 0 0 0 2 0 500 ppm 1hr_uncorrected
1 TRUE 310 CO 5 0.23% 0 0 0 5 0 500 ppm 1hr_at_0%O2
1 TRUE 310 H2S 4 0.19% 0 0 3 1 0 162 ppm 3hrRA
1 TRUE 310 H2S 12 0.56% 0 0 9 3 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 549 25.42% 0 0 549 0 0 250 ppm 12hrRA_at_0%O2
1 TRUE 310 SO2 107 4.95% 0 56 51 0 0 250 ppm 12hrRA_at_0%O2
1 310 0 0 0 0 0 0 0 0 0
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
0
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
FCC Regenerator Vent
Flare #1
Flare #2
FCC Regenerator Vent
FCC Regenerator Vent
Flare #2
Flare #3
Flare #3
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
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
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
0
Point Source
Chevron Refinery EER 1Q2025
1 Type Code 300 (CMSPerformance 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 2160 1.54% 33.25 32 0 0 1.25 0
1 TRUE 300 O2 2160 1.54% 33.25 32 0 0 1.25 0
1 TRUE 300 Opacity 2160 0.05% 1 0 0 0 1 0
1 TRUE 300 CO 2160 4.46% 96.25 47 0 44.5 4.75 0
1 TRUE 300 NOx 2160 4.46% 96.25 47 0 44.5 4.75 0
1 TRUE 300 SO2 2160 4.46% 96.25 47 0 44.5 4.75 0
1 TRUE 300 CO2 2160 4.46% 96.25 47 0 44.5 4.75 0
1 TRUE 300 O2 2160 4.46% 96.25 47 0 44.5 4.75 0
1 TRUE 300 H2S 2160 1.22% 26.25 0 0 25 1.25 0
1 TRUE 300 TRS 2160 2.59% 56 54.25 0 0 1.75 0
1 TRUE 300 H2S 2160 3.76% 81.25 29.75 0 50.5 1 0
1 TRUE 300 TRS 2160 2.22% 48 46.25 0 0 1.75 0
1 TRUE 300 H2S 2160 1.53% 33 9.5 0 22.5 1 0
1 TRUE 300 TRS 2160 0.07% 1.5 0.5 0 0 1 0
1 TRUE 300 H2S 2160 3.81% 82.25 37.25 0 44.5 0.5 0
1 TRUE 300 SO2 2160 0.43% 9.25 1.75 0 0 7.5 0
1 TRUE 300 O2 2160 0.43% 9.25 1.75 0 0 7.5 0
1 TRUE 300 SO2 2160 5.56% 120 117.75 0 0 2.25 0
1 TRUE 300 O2 2160 5.56% 120 117.75 0 0 2.25 0
1 300 0 0 0 0 0 0
1 Type Code 250
(Performance SpecificationRATA 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
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
Flare #3
Flare #1
Flare #1
Flare #2
Flare #2
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 1
SRU Tailgas Incinerator 1
Boiler #7
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Boiler #7
Boiler #7
FCC Regenerator Vent
SRU Tailgas Incinerator 2
FCC Regenerator Vent
Flare #1
Flare #2
Flare #3
Fuel Gas Mix Point
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
Point Source
Point Source
0
FCC Regenerator Vent
FCC Regenerator Vent
FCC Regenerator Vent
Boiler #7
0
SRU Tailgas Incinerator 1
Chevron Refinery EER 1Q2025
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 02/04/25 1 CC63048 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 135.2 135.4 -17.00% P Low
1 Valid Cal. Gas 260 NOx 02/04/25 2 CC3688 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 278.7 276.1 95.00% P High
1 Valid Cal. Gas 260 O2 02/04/25 1 EB0027762 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -40.00% P High
1 Valid Cal. Gas 260 O2 02/04/25 2 CC316355 05/01/26 EPA Traceability Protocol (Sept. 1997)ppm 8 8 0.00% P High
1 Valid Cal. Gas 260 CO 02/05/25 1 CC96320 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 241 249.9 -355.00% P Low
1 Valid Cal. Gas 260 CO 02/05/25 2 EB0157339 08/02/31 EPA Traceability Protocol (Sept. 1997)ppm 529.2 552.2 -417.00% P High
1 Valid Cal. Gas 260 CO2 02/05/25 1 CC200802 03/20/31 EPA Traceability Protocol (Sept. 1997)ppm 6.5 6.5 0.00% P Low
1 Valid Cal. Gas 260 CO2 02/05/25 2 CC487479 03/02/31 EPA Traceability Protocol (Sept. 1997)ppm 14 14 0.00% P High
1 Valid Cal. Gas 260 NOx 02/05/25 1 CC320573 01/03/31 EPA Traceability Protocol (Sept. 1997)ppm 56.2 55.5 128.00% P Low
1 Valid Cal. Gas 260 NOx 02/05/25 2 CC262317 05/23/30 EPA Traceability Protocol (Sept. 1997)ppm 111.2 111.1 12.00% P High
1 Valid Cal. Gas 260 O2 02/05/25 1 EB0123082 05/31/31 EPA Traceability Protocol (Sept. 1997)% 5 5 -120.00% P Low
1 Valid Cal. Gas 260 O2 02/05/25 2 EB0141908 05/31/31 EPA Traceability Protocol (Sept. 1997)% 8 8.1 -12.00% P High
1 Valid Cal. Gas 260 SO2 02/05/25 1 CC733445 08/22/30 EPA Traceability Protocol (Sept. 1997)ppm 56 55.08 167.00% P Low
1 Valid Cal. Gas 260 SO2 02/05/25 2 SG9121046BAL 08/29/30 EPA Traceability Protocol (Sept. 1997)ppm 111.5 110.3 106.00% P High
1 Valid Cal. Gas 260 H2S 02/06/25 1 CC160176 04/04/27 EPA PROTOCOL II GASppm 61.7 71.44 -1358.00% P Low
1 Valid Cal. Gas 260 H2S 2/6/25 2 CC218776 10/9/26 EPA PROTOCOL II GASppm 143 159 -11 P High
1 Valid Cal. Gas 260 TRS 2/6/25 1 CC512539 5/13/27 EPA PROTOCOL II GASppm 12,860 12,526 3 P Low
1 Valid Cal. Gas 260 TRS 2/6/25 2 CC307030 5/20/25 EPA PROTOCOL II GASppm 27,233 27,571 -1 P High
1 Valid Cal. Gas 260 H2S 2/6/25 1 ALM040013 6/30/26 EPA PROTOCOL II GASppm 70 70 0 P Low
1 Valid Cal. Gas 260 H2S 2/6/25 2 CC90612 6/9/26 EPA PROTOCOL II GASppm 143 159 -10 P High
1 Valid Cal. Gas 260 TRS 2/6/25 1 CC341983 12/4/26 EPA PROTOCOL II GASppm 12,638 12,657 0 P Low
1 Valid Cal. Gas 260 TRS 2/6/25 2 EB0156491 9/23/27 EPA PROTOCOL II GASppm 27,271 27,582 -1 P High
1 Valid Cal. Gas 260 H2S 2/18/25 1 CC148981 5/28/26 EPA PROTOCOL II GASppm 69 70 -3 P Low
1 Valid Cal. Gas 260 H2S 2/18/25 2 CC475553 4/8/27 EPA PROTOCOL II GASppm 145 163 -11 P High
1 Valid Cal. Gas 260 TRS 2/18/25 1 CC231302 4/26/25 EPA PROTOCOL II GASppm 2,334 2,491 -6 P Low
1 Valid Cal. Gas 260 TRS 2/18/25 2 CC260070 4/12/25 EPA PROTOCOL II GASppm 5,350 5,553 -4 P High
1 Valid Cal. Gas 260 H2S 2/4/25 1 ALM044045 3/8/27 EPA Traceability Protocol (Sept. 1997)ppm 72 71 2 P Low
1 Valid Cal. Gas 260 H2S 2/4/25 2 CC429272 4/5/27 EPA Traceability Protocol (Sept. 1997)ppm 169 162 4 P High
1 Valid Cal. Gas 260 O2 2/5/25 1 CC140690 6/7/30 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -1 P Low
1 Valid Cal. Gas 260 O2 2/5/25 2 EB0089076 8/7/28 EPA Traceability Protocol (Sept. 1997)ppm 8 8 0 P High
1 Valid Cal. Gas 260 SO2 2/5/25 1 CC107467 8/29/30 EPA Traceability Protocol (Sept. 1997)ppm 129 126 2 P Low
1 Valid Cal. Gas 260 SO2 2/5/25 2 EB0134129 11/22/29 EPA Traceability Protocol (Sept. 1997)ppm 259 252 3 P High
1 Valid Cal. Gas 260 O2 2/6/25 1 EB0105270 5/31/30 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -1 P Low
1 Valid Cal. Gas 260 O2 2/6/25 2 CC741651 8/23/29 EPA Traceability Protocol (Sept. 1997)ppm 8 8 -3 P High
1 Valid Cal. Gas 260 SO2 2/6/25 1 CC356043 11/1/30 EPA Traceability Protocol (Sept. 1997)ppm 122 123 -1 P Low
1 Valid Cal. Gas 260 SO2 2/6/25 2 ALM047181 2/1/27 EPA Traceability Protocol (Sept. 1997)ppm 274 250 10 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
1
Type Code 210
(Pollutant Concentration
Exceeded Span of CEM)
Type Code Channel Start Date Start Time End Date End Time Hours
1 48 210 CO 2/18/25 19:51 2/18/25 19:54 0.05
1 48 210 H2S 1/20/25 18:10 1/20/25 18:27 0.28
1 96 210 H2S 1/20/25 18:36 1/20/25 19:06 0.50
1 TRUE 210 H2S 2/18/25 21:45 2/18/25 21:52 0.12
1 210 H2S 2/18/25 22:02 2/18/25 22:06 0.07
1 210 H2S 2/18/25 22:31 2/18/25 22:44 0.22
1 210 H2S 2/18/25 22:54 2/18/25 23:15 0.35
1 210 H2S 2/18/25 23:28 2/18/25 23:32 0.07
1 210 H2S 2/18/25 23:36 2/19/25 0:07 0.52
1 210 H2S 3/5/25 4:57 3/5/25 5:31 0.57
1 210 H2S 3/5/25 5:35 3/5/25 6:56 1.35
1 210 H2S 1/20/25 18:13 1/20/25 18:18 0.08
1 210 H2S 1/20/25 18:40 1/20/25 18:47 0.12
1 210 H2S 1/20/25 18:55 1/20/25 18:59 0.07
1 210 H2S 1/20/25 19:02 1/20/25 19:06 0.07
1 210 H2S 1/20/25 19:09 1/20/25 19:18 0.15
1 210 H2S 1/20/25 19:20 1/20/25 19:32 0.20
1 210 H2S 1/20/25 19:47 1/20/25 19:51 0.07
1 210 H2S 1/20/25 19:58 1/20/25 20:32 0.57
1 210 H2S 1/20/25 21:36 1/20/25 21:40 0.07
1 210 H2S 1/20/25 22:06 1/20/25 22:13 0.12
1 210 H2S 1/20/25 22:40 1/20/25 22:44 0.07
1 210 H2S 1/20/25 22:47 1/20/25 22:55 0.13
1 210 H2S 1/20/25 22:58 1/20/25 23:10 0.20
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 #2
Flare #2
Flare #1
Flare #1
FCC Regenerator Vent
Flare #1
Flare #1
Flare #1
Flare #1
Flare #1
0
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
Boiler #7
Flare #1
Flare #1
Boiler #7
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
Chevron Refinery EER 1Q2025
1 210 H2S 1/20/25 23:32 1/20/25 23:44 0.20
1 210 H2S 1/20/25 23:55 1/20/25 23:59 0.07
1 210 H2S 1/21/25 0:02 1/21/25 0:13 0.18
1 210 H2S 1/21/25 0:18 1/21/25 1:13 0.92
1 210 H2S 1/21/25 1:48 1/21/25 2:06 0.30
1 210 H2S 1/21/25 2:14 1/21/25 2:18 0.07
1 210 H2S 1/21/25 2:21 1/21/25 2:33 0.20
1 210 H2S 1/21/25 2:37 1/21/25 2:48 0.18
1 210 H2S 1/21/25 2:55 1/21/25 3:29 0.57
1 210 H2S 1/21/25 3:33 1/21/25 3:39 0.10
1 210 H2S 2/8/25 14:01 2/8/25 14:04 0.05
1 210 H2S 2/18/25 20:24 2/18/25 20:35 0.18
1 210 H2S 2/18/25 20:51 2/18/25 20:54 0.05
1 210 H2S 2/18/25 21:02 2/18/25 21:13 0.18
1 210 H2S 2/18/25 21:24 2/18/25 21:32 0.13
1 210 H2S 2/18/25 21:46 2/18/25 21:57 0.18
1 210 H2S 2/18/25 22:21 2/18/25 22:28 0.12
1 210 H2S 2/18/25 22:58 2/18/25 23:13 0.25
1 210 H2S 2/18/25 23:21 2/18/25 23:33 0.20
1 210 H2S 3/5/25 3:55 3/5/25 3:59 0.07
1 210 H2S 3/5/25 4:06 3/5/25 4:10 0.07
1 210 H2S 3/5/25 4:17 3/5/25 4:21 0.07
1 210 H2S 3/5/25 4:24 3/5/25 4:28 0.07
1 210 H2S 3/5/25 4:36 3/5/25 5:11 0.58
1 210 SO2 1/1/25 18:19 1/1/25 18:34 0.25
1 210 SO2 1/1/25 18:38 1/1/25 18:50 0.20
1 210 SO2 1/1/25 19:26 1/1/25 19:42 0.27
1 210 SO2 1/2/25 15:00 1/2/25 15:11 0.18
1 210 SO2 1/2/25 18:11 1/2/25 18:40 0.48
1 210 SO2 1/3/25 16:07 1/3/25 16:34 0.45
1 210 SO2 1/3/25 18:34 1/3/25 18:56 0.37
1 210 SO2 1/9/25 15:50 1/9/25 16:34 0.73
1 210 SO2 1/9/25 16:37 1/9/25 16:50 0.22
1 210 SO2 1/9/25 16:52 1/10/25 15:15 22.38
1 210 SO2 1/10/25 19:18 1/10/25 20:59 1.68
1 210 SO2 1/10/25 21:04 1/10/25 21:11 0.12
1 210 SO2 1/10/25 21:17 1/10/25 21:48 0.52
1 210 SO2 1/10/25 23:19 1/10/25 23:35 0.27
1 210 SO2 1/11/25 3:28 1/11/25 3:45 0.28
1 210 SO2 1/22/25 18:56 1/22/25 22:10 3.23
1 210 SO2 1/22/25 22:21 1/22/25 23:15 0.90
1 210 SO2 1/22/25 23:21 1/22/25 23:28 0.12
1 210 SO2 1/22/25 23:30 1/22/25 23:43 0.22
1 210 SO2 1/23/25 11:26 1/23/25 11:30 0.07
1 210 SO2 1/23/25 11:33 1/23/25 11:36 0.05
1 210 SO2 1/23/25 11:39 1/23/25 11:42 0.05
1 210 SO2 3/28/25 4:05 3/28/25 4:15 0.17
1 210 SO2 3/29/25 19:08 3/29/25 19:21 0.22
1 210 SO2 3/29/25 19:55 3/29/25 20:11 0.27
1 210 SO2 1/22/25 6:59 1/22/25 8:01 1.03
1 210 SO2 2/26/25 9:13 2/26/25 9:16 0.05
1 210 SO2 2/26/25 11:31 2/26/25 11:41 0.17
1 210 SO2 2/26/25 11:51 2/26/25 11:54 0.05
1 210 SO2 2/26/25 12:22 2/26/25 12:25 0.05
1 210 SO2 3/5/25 2:44 3/5/25 3:11 0.45
1 210 SO2 3/14/25 21:56 3/14/25 22:01 0.08
1 210 0 1/0/00 0:00 1/0/00 0:00
1
1 Yes
1 48 TC 220 Hours 1135.50 TC 220 Hours 0.00 TC 230 Hours 0.00 Events 0.00 Hours 0.00 Events 0.00 0.00
1 1135.50 TC 300 Hours 0.00 TRUE
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
SRU Tailgas Incinerator 2
0
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
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 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
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
Flare #2
SRU Tailgas Incinerator 1
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 #2
Flare #2
Type Code 210
(Pollutant Concentration
Exceeded Span of CEM)
Type Code 220
(Monitor Outage
During 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)
Type Code 450
(Data Excluded)
Type Code 550
(Changes in Operation in
Control Equipment When
CEM Data Not Available)
Type Code 500
(Boiler Operating Days
w/o 18 Hours of Data)
Yes None Reported None Reported None Reported None Reported None Reported None Reported
Chevron Refinery EER 1Q2025
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 First 2025
Audit Gas Ranges Audit Gas Ranges
AP1 Low AP2 Low AP1 High AP2 High
Boiler #7 NOx 2/4/25 500 135.4 100 to 150
Boiler #7 NOx 2/4/25 500 276.1 250 to 300
Boiler #7 O2 2/4/25 21 5 4 to 6
Boiler #7 O2 2/4/25 21 8 8 to 12
FCC Regenerator Vent CO 2/5/25 1000 249.9 200 to 300
FCC Regenerator Vent CO 2/5/25 1000 552.2 500 to 600
FCC Regenerator Vent CO2 2/5/25 25 6.5 5 to 8
FCC Regenerator Vent CO2 2/5/25 25 14 10 to 14
FCC Regenerator Vent NOx 2/5/25 200 55.5 40 to 60
FCC Regenerator Vent NOx 2/5/25 200 111.1 100 to 120
FCC Regenerator Vent O2 2/5/25 10 5 4 to 6
FCC Regenerator Vent O2 2/5/25 10 8.1 8 to 12
FCC Regenerator Vent SO2 2/5/25 200 55.08 40 to 60
FCC Regenerator Vent SO2 2/5/25 200 110.3 100 to 120
Flare #1 H2S 2/6/25 300 71.44 60 to 90
Flare #1 H2S 2/6/25 300 159.3 150 to 180
Flare #1 TRS 2/6/25 250000 12526 50000 to 75000
Flare #1 TRS 2/6/25 250000 27571 125000 to 150000
Flare #2 H2S 2/6/25 300 69.7 60 to 90
Flare #2 H2S 2/6/25 300 158.8 150 to 180
Flare #2 TRS 2/6/25 250000 12657 50000 to 75000
Flare #2 TRS 2/6/25 250000 27582 125000 to 150000
Flare #3 H2S 2/18/25 300 70.46 60 to 90
Flare #3 H2S 2/18/25 300 163 150 to 180
Flare #3 TRS 2/18/25 250000 2491 50000 to 75000
Flare #3 TRS 2/18/25 250000 5553 125000 to 150000
Fuel Gas Mix Point H2S 2/4/25 300 70.76 60 to 90
Fuel Gas Mix Point H2S 2/4/25 300 161.6 150 to 180
SRU Tailgas Incinerator 1 O2 2/5/25 21 5.02 4 to 6
SRU Tailgas Incinerator 1 O2 2/5/25 21 8.05 8 to 12
SRU Tailgas Incinerator 1 SO2 2/5/25 500 125.7 100 to 150
SRU Tailgas Incinerator 1 SO2 2/5/25 500 251.6 250 to 300
SRU Tailgas Incinerator 2 O2 2/6/25 21 5.04 4 to 6
SRU Tailgas Incinerator 2 O2 2/6/25 21 7.97 8 to 12
SRU Tailgas Incinerator 2 SO2 2/6/25 500 123.2 100 to 150
SRU Tailgas Incinerator 2 SO2 2/6/25 500 249.5 250 to 300
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 2/5/25 7 -0.170 -0.170 0.003 0.479
FCC Regenerator Vent Flue Gas
Duct 2/5/25 7 0.120 0.120 0.002 0.359
FCC Regenerator Vent Flue Gas
Duct 2/5/25 7 0.420 0.420 0.002 0.624
Audit Gas Used High Span Audit Gas UsedPoint Source Channel Audit Date Low Span
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 1Q2025
Monitoring Information TC 210, 230, & 240
Type Code 210(Pollutant ConcentraƟon Exceeded Span of CEM) - 500(All)
*
Sum of Hours Column Labels
Row Labels (blank) CO H2S SO2 Grand Total
(blank)0 0
FCC Regenerator Vent 1.52 1.52
Flare #1 4.03 4.03
Flare #2 6.88 6.88
SRU Tailgas Incinerator 1 33.68 33.68
SRU Tailgas Incinerator 2 1.88 1.88
Grand Total 0 1.52 10.92 35.57 48.00
*
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 ModificaƟons) - 100 (All)
*
Count of Channel Column Labels
Row Labels (blank) Grand Total
(blank)
(blank)
Grand Total
Chevron Refinery EER 1Q2025
Type Code 220
(Monitor Outage During Point Source Operation) - 600 (All)
*
Sum of Hours Column Labels
Row Labels 724 723 721 Grand Total
FCC Regenerator Vent
Opacity
Quarterly Audit 1.0 1.0
CO
Quarterly Audit 2.5 2.5
Daily Validation 44.5 44.5
Technicians replaced sample conditioning box. 2.3 2.3
PLC did not run daily autovalidation. Technician looked into PLC and
noticed an erroneous calibration value. He changed the value and
revalidated the analyzer.
47.0 47.0
CO2
Quarterly Audit 2.5 2.5
Daily Validation 44.5 44.5
Technicians replaced sample conditioning box. 2.3 2.3
PLC did not run daily autovalidation. Technician looked into PLC and
noticed an erroneous calibration value. He changed the value and
revalidated the analyzer.
47.0 47.0
NOx
Quarterly Audit 2.5 2.5
Daily Validation 44.5 44.5
Technicians replaced sample conditioning box. 2.3 2.3
PLC did not run daily autovalidation. Technician looked into PLC and
noticed an erroneous calibration value. He changed the value and
revalidated the analyzer.
47.0 47.0
SO2
Quarterly Audit 2.5 2.5
Daily Validation 44.5 44.5
Technicians replaced sample conditioning box. 2.3 2.3
PLC did not run daily autovalidation. Technician looked into PLC and
noticed an erroneous calibration value. He changed the value and
revalidated the analyzer.
47.0 47.0
O2
Quarterly Audit 2.5 2.5
Daily Validation 44.5 44.5
Technicians replaced sample conditioning box. 2.3 2.3
PLC did not run daily autovalidation. Technician looked into PLC and
noticed an erroneous calibration value. He changed the value and
revalidated the analyzer.
47.0 47.0
Flare #1
H2S
Quarterly Audit 1.3 1.3
Daily Validation 25.0 25.0
TRS
Quarterly Audit 1.8 1.8
Total Sulphur analyzer experienced high ambient temperature in shack.
This caused it to go into fault status, which disabled the validations.
Technicians corrected HVAC settings, calibrated and revalidated analyzer.
51.0 51.0
Total Sulphur analyzer lost communication with PLC. Analyzer team
performed a hard reset on the analyzer. Communication was restored
and team revalidated anayzer.
3.3 3.3
Flare #2
H2S
Quarterly Audit 1.0 1.0
Daily Validation 22.0 22.0
Misc. Cal Drift, calibrated and revalidated. 0.5 0.5
Analyzer bottles were not proper lined up after CGA. Technicians relined
up calibration bottles and reran validation. 29.3 29.3
PLC stayed in validation mode after morning validation. Technician
calibrated and revalidated manually, then ran in auto for verification of
normal mode. No further issues.
28.5 28.5
Chevron Refinery EER 1Q2025
Sum of Hours Column Labels
Row Labels 724 723 721 Grand Total
TRS
Quarterly Audit 1.8 1.8
Misc. Cal Drift, calibrated and revalidated. 16.5 16.5
Analyzer bottles were not proper lined up after CGA. Technicians relined
up calibration bottles and reran validation. 29.7 29.7
Flare #3
H2S
Quarterly Audit 1.0 1.0
Daily Validation 22.5 22.5
Misc. Cal Drift, calibrated and revalidated. 1.0 1.0
Cal drift, Technicians trouble shot analyzer and adjusted valve timing on
GC. Recalibrated and revalidated. 8.5 8.5
TRS
Quarterly Audit 1.0 1.0
Misc. Cal Drift, calibrated and revalidated. 0.5 0.5
Fuel Gas Mix Point
H2S
Quarterly Audit 0.5 0.5
Daily Validation 44.5 44.5
Air valve gas bottle ran out of air. Technicians quickly replaced air gas
bottle and recalibrated and revalidated.8.3 8.3
Analyzer did not validate due to being in fault status. Technicians reset
the fault. Calibrated and revalidated the analyzer. 29.0 29.0
SRU Tailgas Incinerator 1
SO2
Quarterly Audit 7.5 7.5
Misc. Cal Drift, calibrated and revalidated. 1.7 1.7
O2
Quarterly Audit 7.5 7.5
Misc. Cal Drift, calibrated and revalidated. 1.7 1.7
SRU Tailgas Incinerator 2
SO2
Quarterly Audit 2.2 2.2
Misc. Cal Drift, calibrated and revalidated. 0.2 0.2
Calibration drift, Analyzer team re-established aspirator air, calibrated
analyzer and reran validation. 44.5 44.5
Moisture in sample system shut down sample pump. Team cleaned out
moisture in sample system and recalibrated and revalidated analyzer.
Operations has been advised to adhere to protocol regarding Analyzer
callouts.
73.0 73.0
O2
Quarterly Audit 2.2 2.2
Misc. Cal Drift, calibrated and revalidated. 0.2 0.2
Calibration drift, Analyzer team re-established aspirator air, calibrated
analyzer and reran validation. 44.5 44.5
Moisture in sample system shut down sample pump. Team cleaned out
moisture in sample system and recalibrated and revalidated analyzer.
Operations has been advised to adhere to protocol regarding Analyzer
callouts.
73.0 73.0
Boiler #7
NOx
Quarterly Audit 1.3 1.3
Zero gas regulator failed to open. This failed the daily validation.
Technicians replaced the faulty regulator and reran the daily validation.
No further issues.
32.0 32.0
O2
Quarterly Audit 1.3 1.3
Zero gas regulator failed to open. This failed the daily validation.
Technicians replaced the faulty regulator and reran the daily validation.
No further issues.
32.0 32.0
Grand Total 55.0 336.5 744.0 1135.5
Chevron Refinery EER 1Q2025
Opy *
Opy Count of Magnitude of Emissions Column Labels
Opy Row Labels 704 Grand Total
Opy FCC Regenerator Vent 87 87
Opy
During Safety Instrument System (SIS) testing the reactor level was
increasing and the level controller didn't respond due to it being in
test mode. Slide valve interlocks engaged which shut down the FCC
unit. The unit was placed in safe mode, which pulls feed from the
reactor and steams out any hydrocarbon which eliminated the CO
and opacity exceedances. This event also caused an H2S
exceedance at flares 1 and 2. Operations swept the flares with
sweet gas to eliminate that exceedance. Operations also followed
procedures to safely restart the FCC. The refinery does not have a
history of emissions associated with this cause.
87 87
Opy Grand Total 87 87
SO2 *
SO2 Type Code 410 (SO2) - 6000 (All)
SO2 *
SO2 Count of Magnitude of Emissions Column Labels
SO2 Row Labels 702 703 Grand Total
SO2
An elemental sulfur leak was discovered in SRU #1 that required
the unit to be placed in standby mode in order for operations to
locate and repair the leak. During the course of time operations
worked diligently and followed safety procedures to locate and
repair the leak. This 12 hour SO2 exceedance originated in 4Q24.
The leak was repaired in January and the SRU was pulled out of
standby mode and feed was introduced which eliminated the
exceedance. The refinery does not have a history of emissions
associated with this cause.
SO2 SRU Tailgas Incinerator 1 549 549
SO2
Amine #2 regenerator was swinging on pressure and temperature,
resulting in inconsistent acid gas feed to the SRU #2 and the final
sulfur trap did not reseat properly during the swings. This allowed
for vapor breakthrough of acid gas to the incinerator with higher
levels of SO2, which caused the exceedance. Operations made
process moves to reduce the Amine #2 pressure and temperature
swings. They also cleaned the final sulfur trap to mitigate any vapor
breakthrough. The refinery does not have a histoy of emissions
associated with this cause.
SO2 SRU Tailgas Incinerator 2 40 40
SO2
The steam flow meter on the sour water stripper froze. This caused
the steam valve to stay open increasing steam and water which
flooded and caused carryover to SRU #2. In turn, the reaction
capability was less affective, resulting in elvated SO2 levels to the
incinerator. Operations resolved the issue by replacing the
absorbent with new dry media. The refinery does not have a
history of emissions associated with this cause.
Chevron Refinery EER 1Q2025
SO2 SRU Tailgas Incinerator 2 56 56
SO2
Console Operator started to get detectable amounts of H2S in the
RFG system. To reduce the H2S, the console operator moved amine
to the regenerator, which already had a high level of amine. This
caused temperature and pressure swings in the regenerator. As a
result excess H2S was sent to the flare. The console operator was
able to stabilize the temperature by manually operating the steam
to the regen boiler to eliminate the H2S exceedance. Additionally
this caused a valve to open, which swung the pressure at the SRU
#2. This caused an increase of SO2 to the incinerator. The Console
operator then worked to close the valve, stopping the excess
pressure in the SRU which eliminated the SO2 exceedance. The
refinery does not have a history of exceedances associated with
this cause.
SO2 SRU Tailgas Incinerator 2 11 11
SO2 Grand Total 56 600 656
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
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 703 704 Grand Total
H2S/TRS Flare #1
H2S/TRS
During Safety Instrument System (SIS) testing the reactor level was
increasing and the level controller didn't respond due to it being in
test mode. Slide valve interlocks engaged which shut down the FCC
unit. The unit was placed in safe mode, which pulls feed from the
reactor and steams out any hydrocarbon which eliminated the CO
and opacity exceedances. This event also caused an H2S
exceedance at flares 1 and 2. Operations swept the flares with
sweet gas to eliminate that exceedance. Operations also followed
procedures to safely restart the FCC. The refinery does not have a
history of emissions associated with this cause.
1 1
H2S/TRS
Console Operator started to get detectable amounts of H2S in the
RFG system. To reduce the H2S, the console operator moved amine
to the regenerator, which already had a high level of amine. This
caused temperature and pressure swings in the regenerator. As a
result excess H2S was sent to the flare. The console operator was
able to stabilize the temperature by manually operating the steam
to the regen boiler to eliminate the H2S exceedance. Additionally
this caused a valve to open, which swung the pressure at the SRU
#2. This caused an increase of SO2 to the incinerator. The Console
operator then worked to close the valve, stopping the excess
pressure in the SRU which eliminated the SO2 exceedance. The
refinery does not have a history of exceedances associated with
this cause.
3 3
H2S/TRS Flare #2
Chevron Refinery EER 1Q2025
H2S/TRS
During Safety Instrument System (SIS) testing the reactor level was
increasing and the level controller didn't respond due to it being in
test mode. Slide valve interlocks engaged which shut down the FCC
unit. The unit was placed in safe mode, which pulls feed from the
reactor and steams out any hydrocarbon which eliminated the CO
and opacity exceedances. This event also caused an H2S
exceedance at flares 1 and 2. Operations swept the flares with
sweet gas to eliminate that exceedance. Operations also followed
procedures to safely restart the FCC. The refinery does not have a
history of emissions associated with this cause.
3 3
H2S/TRS
The level indication on the High Pressure Separator in the VGO was
not reading correctly due to the product freezing. This caused the
pressure to elevate in the High Pressure Seperator and lift the relief
valve.This relief valve opened to the Coker flare where it breached
the water seal. Operation teams added heat blankets and steam
hoses to stop the product from freezing. They also swept the flare
with sweet gas to eliminate the exceedance. The refinery does not
have a history of emissions associated with this cause.
9 9
H2S/TRS Grand Total 12 4 16
CO *
CO Type Code 440
(CO) - 6000 (All)
CO *
CO Count of Magnitude of Emissions Column Labels
CO Row Labels 704 Grand Total
CO FCC Regenerator Vent
CO
During Safety Instrument System (SIS) testing the reactor level was
increasing and the level controller didn't respond due to it being in
test mode. Slide valve interlocks engaged which shut down the FCC
unit. The unit was placed in safe mode, which pulls feed from the
reactor and steams out any hydrocarbon which eliminated the CO
and opacity exceedances. This event also caused an H2S
exceedance at flares 1 and 2. Operations swept the flares with
sweet gas to eliminate that exceedance. Operations also followed
procedures to safely restart the FCC. The refinery does not have a
history of emissions associated with this cause.
7 7
CO Grand Total 7 7
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 1Q2025
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