DAQ-2025-000311

,.dttF$nctorr
July 31,2024
Director, Air Enforcement Division
Office of Civil Enforcement
U.S. Environmental Protection Agency
MailCode 2242-A
1200 Pennsylvania Avenue, N.W.
Washington, DC 20460-0001
Executive Secretary, Utah Air Quality Board
Division of Air Quality
195 North 1950 West
P.O. Box 144820
Salt Lake City, UT 84116-4820
CIIRTIFIED MAIL: 7022 0410 0002 3551 6448
UTAH DEPARTMEiT OF
ETWIBONMENTAL OTJAUTV
AUG - 1 2C?4
DIV'SION OF AIR QUALTV
RE: Semiannual Progress Report
Consent Decree Entered July 2, 2008 in the U.S. District for the District of Utah
United States of America, State of Utah v. Holly Refining & Marketing Company - Woods
Cross
Dear Director and Executive Secretary:
In accordance with Paragraphs 135,147, and 149 of the subject consent decree, this submittal provides
the progress report for the Woods Cross Refinery fbr the semi-annual period from January I through June
30,2024.
ln accordance with Paragraph 149d, the following certification is provided:
I certify under penalty of law that this information was prepared under my direction or supervision by
personnel qualified to properly gather and evaluate the information submitted. Based on my directions
and after reasonable inquiry of the person(s) directly responsible for gathering the information, the
information submitted is, to the best of my knowledge and belief, true, accurate, and complete.
ln accordance with Paragraph 261 , copies of this repofl are also provided to EPA Region 8 and other
required governmenl representatives.
Sincerely,
Dustin Simmonds
Vice President and Refinery Manager
llf Srttr;larr \{i.icrcis Crr.rss Rr:lrrrirrq [ [ C
1070 y/ 500 S \\/est Rorrntifrrl l.,l 84067
801 -299-6600 | HFSinclair.conr
REVIEWEDInitials: Date: Jan 17, 2025Complionace Status:OKFile #: 10123 (B2)
luly 31,2024
Director, Air Enforcement Division, et. al.
Page 2
Director, Air Enforcement Division
Office of Civil Enforcement
c/o Matrix New World Engineering Inc.
26 Columbia Tumpike,2nd Floor
Florham Park, NJ 07932
Megan J. Houdeshel
Dorsey & Whitney LLP
I I I S. Main Street, Suite 2100
salt Lake city, uT 84ltl-2176
csu I I ivan(a)matrixneworld.com
lb Ie v. patrick(ri; eDa. sov
sal la ghcr.bob(alepamai l.epa. eov
T. Go
Air Program Director
Offrce of Enforcement, Compliance & Environmental Justice
Environmental Protection Agency, Region 8
1595 Wynkoop Street
Denver, CO 80202-1129
T. Jones
R. Bagherian
E. Benson (4) File 2.6.3.1.149
Progress Report on the Implementation of the Requirements
of Part V (Affirmative Relief/Environmental projects)
CD TI Requirement Stetus/Comment
Section V.A. NOx Emissions Reductions from the FCCU
t2 Submit detailed design for NOx Control
System bv l2l3lll0.Complete. Design sent I l/15/10.
l3 Install and begin operation of NOx Control
System bv l2l3ll12.Complete. Operation began 10127 I 12.
14
Commence I 5-month interim
demonstration period to determine interim
FCCU NOx limit bv 4ltl09.
Data collection for NOx emissions from the
FCC began 4lll09 and was completed 6/30110.
l5 Report results of interim NOx
4emonstration by 90 days followins period.Complete. Interim report sent 9l29ll\.
16 Propose and comply with 7-day and 365-
day interim NOx limits.
Complete. Interim NOx limits proposed in
interim report of 180 ppm 7-day average and
I l0 ppm 365-day average.
17
Comply with or dispute EPA-established
interim NOx limits within 90 days of
receipt.
EPA-established limits received and complied
with until final limits were set.
l9
Commence I S-month demonstration period
upon startup of NOx Control System to
determine final FCCU NOx limit.
Complete. Final demonstration period
concluded on3l30l14.
20 Report results of final NOx demonstration
by 90 days following period.Complete. Final report sent 517 I 14.
2t Propose and comply with 7-day and 365-
day final NOx limits.
Complete. Final NOx limits proposed in final
report of80 ppm 7-day average and 40 ppm
365-day average and monitoring.
22 Comply with or dispute EPA-established
final NOx limits within 90 days of receipt.
Final limits submitted to EpA on 5l7l14. EpA
established final NOx limits, received
11/17120, of 40 ppm 7-day average and22.5
ppm 365-day average. We are complying with
those limits.
23 Use NOx and Oz CEMS to monitor FCCU
performance bv 4lll09.
Complete. NOx and Oz CEMS installed and
collecting emissions data 4/l/09.
Section V.B. SOz Emissions Reductions from the FCCI
25
Install and begin operation of a Wet Gas
Scrubber at the FCCU by t2l3tlt2 and
meet 25 ppm (365-day) and 50 ppm (7-
dav) bv 6130113.
Complete. Wet Gas Scrubber installed
10/27112. We are complying with these limits.
26
Commence I S-month interim
demonstration period to determine interim
FCCU SOz limit bv 4ltl09.
Complete. Data collection for SOz emissions
from the FCC began 4lll09 and was
completed 6130110.
27 Report results of interim SOz
demonstration by 90 days followine oeriod.Complete. Interim report sent 9lL9ll0.
CD qI Requirement Status/Comment
28 Propose and comply with 7-day and 365-
day interim SOz limits.
Complete. Interim SOz limits proposed in
interim report of 160 ppm 7-day average and
50 ppm 365-day average.
29
Comply with or dispute EPA-established
interim SOz limits within 90 days of
receipt.
EPA-established limits received, and complied
with those limits until the lower limits became
effective.
3l Use SOz and Oz CEMS to monitor FCCU
performance bv 4lll09.
Complete. SOz and Oz CEMS installed and
collecting emissions data 4lll09.
Section V.C. PM Emissions Reductions from the FCC U
32
Comply with limit of 1.0 pounds PM per
1000 pounds coke burned for FCCU by
6t30t13.
Complete. PM performance testing completed
on 12120112. Report sent to EPA ll23ll3.
33
Install and begin operation of a Wet Gas
Scrubber at the FCCU by 12l3tl12.
Comply with limit of 0.5 pounds pM per
I 000 pounds coke burned for FCCU by
6130fi3.
Complete. PM performance testing completed
on 12120/12. Report sent to EPA 1123113.
35
Perform PM test on FCCU by l0/31/13 and
annually thereafter by l0/31 . Submit
results in next semiannual report.
Initial PM performance testing completed on
l2l20l12. Results sent to EPA under separate
cover letter ll23ll3. First annual PM test
completed 10122/13. Second annual pM test
completed l0l2l14. Third annual pM test
completed l0l22l15. Fourth annual pM test
completed l2l7l16. Fifth annual PM test
completed l0l25l17. Sixth annual pM test
completed l0ll9l18. Seventh annual pM test
completed 9l4ll9. First triennial pM test
completed 61 14122. Additional pM test
completed 916123. Request to reduce testing
frequency was submitted to USEpA 6126/lg.
Request for triennial testing granted 916l19.
Section V.D. CO Emissions Reducrions from the FCC[
36 Comply with 500 ppm CO (l-hour) ar
FCCU by t2l3ll09.Complete. Monitoring CO emissions.
37 Option to comply with 100 ppm CO (365-
day) at FCCU.Option is not currently under consideration.
39 Use CO and Oz CEMS to monitor FCCU
performance bv l2l3l 109.
Complete. CO and Oz CEMS installed and
collecting emissions data 4l I I 09.
Section Y.E. NSPS Applicability of the FCCU Catalyst Regenerator
4l FCCU subject to NSPS for CO by
12131109, and for SOz and PM by Gt30/13.
CO limit complete, 500 ppm CO (l-hour) at
FCCU. Wet Gas Scrubber installed and now
complying with SO2 and PM NSpS limits.
43 Install and operate a COMS on the FCCU
by l2l3ll12 or comply with fl44.
Complete. Alternate Monitoring Plan (AMp)
request sent to EPA4ll2l12. Revised AMp
request sent to EPA9127ll2. AMP approval
received l0/24112.
CD !t Requirement StatudComment
44 Request an AMP for monitoring opacity
from the FCCU or comply with fl43.
Complete. Alternate Monitoring Plan (AMp)
request sent to EPA 4ll2l12. Revised AMp
request sent to EPA9127l12.
Section V.F. NOx Emissions Reductions from Heaters and goilers
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on
6H l, or convert the Clark compressor
driver to electric, or replace the Clark
compressor with an electric-driven
compressor bv l2l3 I 109.
Complete. Clark compressor was replaced by
electric driven compressor I lK2. Installation
was complete lll17l09.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on
8Hl by l2l3ll09.
Complete. Installed by 9/9t08.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on
l2H1 bv l2l3ll09.
Complete. Installed by 917/09.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on #5
Boiler bv l2l3ll09.
Complete. Selective Catalytic Reduction
(SCR) alternative NOx Control Technology
was installed on #5 Boiler on 12130109.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on the
CO Boiler by l2l3ll12 if disengaged from
FCCU.
Complete. CO Boiler disengaged from FCCU
10126l12. CO Boiler shut down permanently.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on
Boiler #8by l2l3l/12.
Complete. Boiler shutdown on l2l3ll12 and
restarted lll0l13 with Selective Catalytic
Reduction (SCR) installed.
46a
Install Next Generation ULNBs or
alternative NOx Control Technology on
4Hl by l2l3ll12 if heat input capacity is
raised above 40 mmBTU/hr.
Heat input capacity is at or below 40
mmBTU/hr.
46b( r )
Install and operate NOx and Oz CEMS on
heaters/boilers over 100 mmBTU/hr by
date of NOx Control Technology
installation, and use to monitor emissions
by 6 months later.
No heaters or boilers have heat input
capacities over 100 mm BTU/hr (HHV).
46b(2)
Conduct performance tests on
heaters/boilers equal to or less than 100
mmBTU/hr by 60 days after installation of
NOx Control Technology.
Complete. Performance test on 8H I completed
10/9108. Performance test on l2Hl completed
I 0/ I 3/08. Performance test on #5 Boiler
completed 2l9ll0 and retested 3125/lO.
Performance test on #8 Boiler completed
4122fi3.
46c
Submit permit revision to State proposing
NOx emission limits (3-hour) for any NOy
Control Technology within 120 days of
start-up.
Complete. Notice of Intent for a change in
permit conditions fbr NOx limits on 8Hl and
l2H I submitted 12123108. Notice of Intent for
a change in permit conditions for NOx limits
on #5 Boiler submitted 4129110.
Submit annual NOx Control Technology
progress report by l2l3 I beginning in
2008.
First report submitted lzll5l08. Subsequent
annual reports submitted: l2l2t I 09, l2l22l I 0,
l2/22fi t, t2t2u t2, t2t3t / 13, 12l3ol t4,
t2t29t I 5, t2t28t I 6, t2t27 / 17, t2t3 I I t8,
t2t 30 I I 9, tzl 30120, t2t28 l2o2l, t2t 3012022,
and 1212812023.
Section Y.G. SOz Emissions Reductions from and N
All heaters and boilers are subject to NSpS
Subpart J.
Complete. Prior to Consent Decree, fuel gas
for all heaters and boilers being monitored by
CEM, with quarterly reporting as required by
State of Utah.
May use alternative monitoring method
immediately upon submittal of AMp.
Complete. 2 AMPs submiued June 24,2009,
AMPs were subsequently rescinded.
weight shall be burned in any fuel gas
combustion device.
No liquid fossil fuel over 0.05% Sulfi.r by Complete. None used. Intemal memo sent
detailing limit. Copy and responses filed.
Section V.H. NSPS licabilitv to the Sulfur Plant
NSPS shall apply if SRU exceeds 20
LTPD.
Complete. Maximum SRU capacity is l0
Install and commence operation of SOu
CEMS at SRU bv 712/08.
Complete. CEMS installed and operationai
Demonstrate daily 95% recovery (30 day)
for SRU using measured HuS in feed and
SOz emissions from CEMS.
The calculation of95% recovery from the
of these changes was submitted on 6/9/16.
sulfur recovery unit has become impractical
due to the treatment of off gas from the sulfur
recovery unit by a fluidized catalytic cracking
unit's wet gas scrubber. A detailed summary
Determine HzS in SRU feed quarterly for 4
quarters and semiannually thereafter.
Sampling and analysis completed 9l2ZlOB,
l0l I 61 09, 21 6109, 51 5 109, 7 l2g I 09, tol t2l0g,
I /22/ 10, 8125 I I 0, 0 I 126l I t, 7 l2gl I t, 21281 12,
7 I I 1 I t2, 2t4l t3, 7 l2l 13, 2t tgl 14, 7 l5l 14,
I l2l I I 5, 7 l7 / I 5, and 2l9l I 6. Sampling has
been discontinued. The SRU off gas is treatecl
by a fluidized catalytic cracking unit,s wet gas
scrubber.
Complete SRP Optimization Study,
implement recommendations, and submit
study report within I year after 7l2l0\.
Complete. Optimization Study was completed
and report submitted 6126109. Scheclule of
implementation for the report's
recommendations was included in the report
that was submitted.
Submit test protocolto EPA Region g and
State to perform 95%orecovery efficiency
and emission limit test at least 30 days
before test. Conduct test within 6 months
after completion of SRP Optimization
SRP Optimization Study completed 612612009.
Test protocol was submitted 1112312009.
Testing performed 1212312009, SRU achieved
95.2% recovery and0.42 tons per day (830
lbs) SO2.
Submit a semiannual report covering SRU
recovery, emissions, operating parameters,
and daily feed.
The calculation of 95%o recovery from the
sulfur recovery unit has become impractical
due to the treatment of off-gas from the sulfur
recovery unit by a fluidized catalyic cracking
unit's wet gas scrubber. A detailed summary
of these changes was submitted on 619l16.Submit Plan for Maintenance and
Operation of SRP within 270 days from
712t08.
Complete. plan submitt ed 312612009.
Submit schedule to comply with NSpS
within 120 days of SRU exceeding 20 Maximum SRU capacity has not increased
beyond l0 LTPD.
All sulfur pit emissions routed to
incinerator.
Complete. Commenced prior to Consent
Section V.I. NSPS licability to Flaring Devices
North flare and South flare subject to NSpS
as of date of entry, eliminate all routinely-
generated gas.
Complete. Subject to NSPS prior to Consent-
Decree, no routinely-generated gas sent to
flare. As of November I I , 201 5, all streams
going to the flares are being monitored for
compliance with the NSPS Ja standard, and are
in the quarterly CEMs reDorts.
South flare subject to NSPS 6130109,
eliminate all routinely-generated gas.
Complete. Study completed on routinely-
generated gas sources and rerouting
completed. Alternative Monitoring plans
submitted for 2 streams. (AMps were
Propane flare subject to NSpS l2l3ll09,
eliminate all routinely-generated gas.
Complete. New propane flare installed
llll712009. The propane flare and associated
storage pit were decommissioned in Decemberof20l3.
Conduct performance tests for each flare
within 180 days after bringing into
compliance with NSPS.
Performance tests for both North and South
Flares conducted December 10, 2008.
Performance test for the propane pit flare
conducted March 25. 2010.Comply with 162 ppm HzS limit in fuel Complete. Ongoing prior to Consent Decree.
Section V.J. Control of Acid Gas F
Submit reports for Acid Gas Flaring
Incidents no later than 45 davs after
incident.
No Acid Gas flaring events occurred in period.
Section V.K. Control of Hydrocarbon Flarins Incidents
Submit reports for Hydrocarbon Flaring
Incidents in semiannual progress reports.
Report for the incident on 5/13124 was
completed 6127124. Report submitted on
713U2024.
Section V.L. CERCLA/EPCRA
Report any previously unreported SO2
releases bv 6130109.
No previously unreported SOz releases were
Section V.M.r"-"nt
If TAB exceeds l0 Mg/yr, utilize the 6Be TAB remains under l0 Mg/yr.
Complete review and verification of
refinery's TAB and compliance by 270
days after date ofen
Complete. Sampling plan, review and
verification were completed 3/ 18109.
Submit report to the EPA and State by 60
s after review and verification.Complete. Report submitted 5120109.
Conduct additional sampling and submit
results to EPA within 60 days after EPA requested no additional sampling.
Revise report and resubmit within 120 days
after completion of samplins.Original repoft deemed final.
If revised report indicates initial report was
unsatisfactory, resubmit report to State
within 120 days after completing revised Original report deemed satisfactory.
If revised report indicates TAB over l0
Mglyr, submit plan within 180 days to
ensure future compliance or to comply with
6BQ within 2
No action required. The BWON Compliance
Review and Verification Report did not
indicate that the TAB exceeds l0 Mg/year.
If actions are required under fl 77, submit
certification of compliance within 30 days
after completion of actions.
No action required. Neither the BWON
Compliance Review and Verification Report
nor current sampling pursuant to paragraph 94
indicate that the TAB exceeds l0 M
Develop program within 60 days from date
ofentry to annually review process/project
information to ensure all new benzene
waste streams are included in inventory.
Complete. A task to complete an annual
review was added to the automated
environmental tracking system. Inventory
reviewed on 12130109, l2lL7lt0, l2l30lll,
t2/27 I 12, tzt 19n3, t2t ton4, t2l3on5,
t2/28t | 6, 12t22t2017, 3 t24t 1 8, 12t21 I I 8,
I 2/20 I I 9, t2l | 7 /20, I 2130 t2t, 6/30t2022,
12130122* , and l2l2t 123 ,
*12130122 was omitted in error in the semi-
annual report forthe second halfof2023,
submitted on l/31124. Two reviews were
in2022, as listed above.
CD TI Requirement StatudComment
82,94
Conduct audits ofall laboratories used for
benzene waste analysis within 270 days
after date of entry, new labs before use, and
every two years.
Laboratory audit completed 3/l llll,3lgl13,
3 I 18t I 5, 3l t6l t7, 3t281 t9, 3/22t21, and
3128t23*.
*An incorrect date of 3/8/23 was included in
the semi-annual report for the first half of
2023, submitted on 7l3l/23, as well as the
semi-annual report for the second half of 2023,
submitted on 1/31124.
86
Review spills to determine if they generate
more than l0 lbs ofaqueous benzene
waste, and include in TAB.
Environmental Procedure 5.02 incorporates
review requirements.
87
Develop and begin annual training for all
employees asked to draw benzene waste
samples, complete first within calendar
year.
Initial training completed 05l}llO9. Contract
personnel were initially used to collect
samples. Additional training completed
annually. The latest training was completed on
12t29t23.
89 Ensure contractor employees hired to
perform training are adequately trained.
Completed for contract employees byl2ll5108,l2l8l09, and I l/05/10. Contractors
no longer used.
90,
I 03e
Submit waste/slop/off-spec oi I
management schematics Complete. Sent to State and EpA g/21109.
93,
I 03f
Submit quarterly/annual sampling plans to
EPA and State by 60 days after revised
report is finalized or original report is
accepted.
Original report accepted. Sampling plan sent
on7/2112.
95 Implement the sampling plan in the firsl
full quarter after submittal.
Complete. Sampling plan has been
implemented. The sampling plan is more
stringent than the CD in requiring quarterly
sampling for waste streams > 0.05 Mg/yr
benzene.
96,
I 03f
Ifchanges affect the validity ofthe
sampling plan, submit revised plan within
90 days.
A revised sampling plan was submitted to
EPA on 5125123.
97 Submit quarterly and annual projected
TAB with semiannual report.
The quarterly and annual projected TAB is
included in Attachment B.
98 Implement corrective measures if quarterly
TAB > 2.5 Mg or annual TAB > l0 Me.No excesses during this period.
99 Provide reasons why causes ofexcess
quarterly or annual TAB will not recur.No excesses during this period.
I 00,
I 03g
Submit compliance assurance plan if
quarterly TAB > 2.5 Mgor annual TAB >
l0 Mg.
No excesses during this period.
Contract 3'd party to conduct TAB studi
and compliance review if quarterly TAB >
2.5 Mg or annual TAB > l0 Mg. Submit
results to EPA and State within 30 days
No excesses during this period.
Submit sampling results and TABs with the
semiannual reoort.
Sampling results and TABs are included in
Submit description of training conducted
with the semiannual report.
Retraining completed for 2023 via review of
physical materials based on previous
Submit a summary of lab audits conducted
with the semiannual report.
Identification of the laboratory audited, a
description of the methods used in the audit,
and the results of the audit are provided as
Attachment C.
Requests to modify the frequency of
reportins underfll04.
No request has been made to modify the
Section v.N. Leak Detpgltgqgl4 Bgperr ("LDAR") p.oe.d- Erhancements
Develop and maintain a written LDAR
within 120 days of date of
Complete. Submitted with Semi-Annual
Submit LDAR program to EpA and State
in first semiannual
Complete. Submitted with Semi-Annual
dated 1128109.
Train employees newly assigned to LDAR
responsibilities before beginning LDAR
work.
Computer-based training is required for all
newly involved employees.
Provide annual haining for all employees
with specific LDAR responsibilities as
primary job function beginning within I
Computer-based training program is required
for all employees with specific LDAR
responsibilities as their primary job function.
Provide training every 3 years for all
operations and maintenance employees
beginning within 1 year of 7/2108.
Training program established training for l4t
employees and completed 612109. Training for
160 employees completed l2l2lll l. Training
for 218 employees completed l2l3ll13.
Training for 173 employees completed
12/31 I 15. Training for 207 employees
completed 12/31118. Training for 158
employees completed 2/llZ2.3 year training
for operations and maintenance personnel
typically takes place through computer-based
training (CBT). The refinery transitioned to a
new CBT software system in late 202l.To
facilitate the required training, a training
document was developed to distribute to
personnel, as an alternative. Anti-phishing
safeguards in our email software prevented the
timely distribution of the training. Training
for 163 employees completed l2l22lL3.
10
CD !I Requirement Status/Comment
uld Maintain records of annual training as in !f
I I lb for contract LDAR oersonnel.Maintained under file number 2.6.3.
I 13,
114
Conduct 3'o party audit of LDAR
compliance every 4 years, beginning within
12 months of date of entry.
3'd party audit conducted by ERM and report
submitted 6122109.
lt3 Submit LDAR compliance certification to
EPA.
LDAR compliance certification submitted
1/5t2010.
I 15
Conduct an internal or 3d party audit of the
LDAR program every 4 years, beginning
within 2 years after the initial 3'd party
audit.
3'd party audit conducted,4ll9lll, 4l$l13,
4/ 1 3 I 1 5, 5 I I 61 17, 41 1 I I 19, 4/221 21, and 5 I 4 /23.
l16 LDAR audits are to be conducted in the
same calendar quarter.
All future LDAR audits will be conductecl the
lgggqd calendar quarter ofthe year.
117
Implement steps necessary to correct areas
of non-compliance identified in the
Consent Decree required LDAR audits.
All corrective actions identified in the first
LDAR Audit conducted 5/26-5129109 are
complete. Corrective actions for the second
and third audits are complete. Corrective
actions for the fourth audit are complete.
Corrective actions for the fifth audit are
complete. Corrective actions for the sixth
audit are complete. Corrective actions for the
seventh audit are complete.
120
Utilize intemal leak definition of 500 ppm
for valves, except pressure reliefdevices,
by llll09.Complete.
t2t Utilize internal leak definition of 2,000
ppm for pumps by 7/l/10.Complete.
122
Specify in report whether applicable
regulatory leak definition or lower internal
leak definitions are being used for leak
rates.
Applicable regulatory leak definition is used
for reporting leak rates.
124
Make initial attempt at repair on non-
control valves with reading over 200 ppm
and remonitor.
Complete.
125 Monitor pumps in light service monthly
beginning 7llll0.Complete.
126 Monitor valves, other than difficult to
monitor valves, quarterly beginning l/l/09 Complete.
127 Keep LDAR data in electronic database Complete.
r28 Use dataloggers/electronic data collection
for LDAR.Complete.
129
Develop and implement a LDAR eA/eC
procedure within 90 days after date of
entry.
Complete.
11
CD TI Requirement Status/Comment
130
All LDAR equipment calibrations to be
conducted per Method 21, and records
maintained for life of Consent Decree.
As specified in procedures, see Semi-Annual
Report dated 1128109, Attachment B.
l3l
Drift assessments performed at minimum at
the end of each shift, with remonitoring if
negative drift exceeds 10%.
Complete.
132a
Sign offby responsible person for delay of
repair, and continued monitoring of
equipment.
Complete.
t32b
Employ "drill and tap" for valves leaking
over 10,000 ppm that cannot otherwise be
repaired.
As required, and as specified in procedures,
see Semi-Annual Report dated, I l21l09,
Attachment B.
134
Repair or replace non-control valves that
are chronic leakers at next process unit
furnaround.
As required, and as specified in procedures,
see Semi-Annual Report dated, I 128109,
Attachment B.
I 35a Provide LDAR program information in the
first semiannual report.Complete.
r 35b
Provide description ofaudit report for each
audit conducted in the prior year in the
semiannual report (July 3l report only).
Identification of the auditor, a summary of the
audit results, and the status of Holly's actions
related to the audit are provided as Attachment
D.
136
Provide information on training and on
LDAR monitoring and repairs in the
regular NESHAPS reDorts.
Included in Semiannual MACT reports
beginning January 2009.
Section V.O. Incorporation of Consent Decree Requirem
l37a
Submit permit revision for immediate
Consent Decree requirements within 90
days of date of entry.
Notice of Intent for a change in Approval
Order (AO) conditions to incorporate Consent
Decree requirements submitted gllg/09. AO #
DAQE-AN0 101230027 -09 received t t D toq
t2
CD !l I nequirement Status/Comment
137b
Submit permit revision for other Consent
Decree requirements within 90 days of
effective date.
Notice of Intent for a change in Approval
Order (AO) conditions for NOx limits on 8Hl
and l2Hl submitted 12123108. AO # DAeE-
ANol0l 230027 -09 received I I lll09. Notice
of Intent for a change in AO conditions for CO
limit on FCCU submitted 3129110. AO #
DAQE-AN0 101230032-10 received 8t23 I t0.
Notice of Intent for a change in AO conditions
for #5 Boiler NOx limit submitted 4ll9ltO.
AO # DAQE-AN0 I 01230036- I 0 receivedllll7ll0. Notice of Intent for a change in AO
conditions for interim NOx and SOz limits on
FCCU submitted tU30n0. Ao # DAQE_
ANO101230038-10 received t2lt6llO. Notice
of Intent for a change in AO conditions for
final SOzlimits on FCCU submitted 51231t2.
Notice of Intent for a change in AO conditions
for interim NOx limits on FCCU submitted
3123t13. AO # DAQE-ANl0l23004t_13
received llll8ll3. AO # DAQE-
AN101230052-20 received 1018120. Notice of
Intent for a change in AO conditions for final
NOx limits on FCCU submitted 214/2021. AO
# DAQE-AN 101230053-22 received 9 / 1 t22
Summary of the Emissions Data Required by the Reporting Requirements
of Part V (Aflirmative Relief/Environmental projects)
Description of Any Problems Anticipated with Respect to Meeting the Requirements
of Part V (Affirmative Relief/Environmental projects)
None for this report.
Section V.H. NSPS Applicabilitv to the Sulfur plant
Submit a semiannual reporl covering SRU
recovery, emissions, operating parameters,
and daily feed.
The calculation of 95%o recovery from the
sulfilr recovery unit has become impractical
due to the treatment of off gas from the sulfi.u
recovery unit by a fluidized catalytic cracking
unit's wet gas scrubber. A detailed summary of
these changes was submifted on 619l16.
13
CD II Requirement Status/Comment
Section YII. State Supplemental Environmental projec
l45a
Contribute $ 130,000 for purchase of
mobile command post, which shall be
acquired within I year of date of entrv.
Complete. Delivery of mobile command post
418109. Public presentation 5l l9l}9.
I 45b
Submit a cost report and certification in
the semiannual report upon completion of
project.
Complete. Submitted with Semi-Annual
Report dated 7 129 109, Attachment D.
147 Provide a progress report for the SEP in
each semiannual report.
Complete. Submitted with Semi-Annual
Report dated 7 129109. Artachment D.
Progress Report on the Implementation of the Requirements
of Part VII (State Supplemental Environmental project)
Any Additional Matters to be Brought to the Attention of EPA and the State
None for this report.
Summary of Annual Emissions Data for the prior calendar year
CD II Reouirement Status/Comment
Section lX. Reporting and Recordkeeping, fl149b. Emissions Data
l49b
Estimation of NOx emissions for each
heater and boiler greater than 40
mmBtu/hr.
6Hl ; 19.20 tpy, 8Hl; 10.22 tpy, l2Hl; 5.95
tpy,20H2; 6.49 tpy, #5 Boiler; 0.14 tpy, #6
Boiler; 0.0 tpy (decommissioned in 20lZ), #B
Boiler; 0.08 tpy, #9 Boiler; 0.74 tpy,#10
Boiler; l.l I tpy, #l I Boiler; 2.44 tpy. All NOx
emissions for 8Hl, l2Hl,#5 Boiler, #8 Boiler,
#9 Boiler, #10 Boiler, and #l I Boiler were
estimated using stack testing results. AllNOx
emissions for 6Hl and20H2 were estimated
using emission factors.
t49b Estimate of NOx emissions as a sum for all
heaters and boilers less than 40 mmBtulhr.
Estimated NOx emissions for all heaters and
boilers less than 40 mmBtu/hr for the 2023
reporting year; 42.20 tpy (emission factors).
t49b Estimate of SOz, CO and PM emissions as
a sum for all heaters and boilers.
Estimated emission for the 2023 reporting year
are as follows: SOz; 9.02tpy (CEMS), CO;
144.59 tpy (emission factor & stack testing),
PM (PMl0); 5.93 tpy (emission factor & stack
testing), (PM2.5); 0.99 tpy (emission factor &
stack testing).
t49b Estimate of SOz emissions llom all Sulfur
Recovery Plants.
Estimated SOz emissions for the 2023 reporting
year from all Sulfur Recovery Plants is 0 tpy(All SRU emissions are routed to a FCCU
wGS).
74
t49b SOz emissions from all acid gas flaring
incidents by flare.
Reporting year 2023 had no acid gas flaring
incidents.
t49b
NO1, SO2, PM, and CO emissions as a
sum at each refinery for all other emissions
units for which emissions information is
required to be included in the facilities'
AEI not identified above.
Estimated emission for all other emissions units
for the 2023 reporting year are as follows: NO*;
24.24 tpy, SOzt 3.12 tpy, CO; 140.06 tpy, pM
(PMl0); I1.06 tpy, (PM2.5); I1.06 tpy,
Exceedances of Emission Limits
Section IX. Reporting and Recordkeeping, fl149c. Exceedanc"ioiE-irrion Li*is
Interim NOx 7-day rolling average,
corrected to 0oZ oxygen, from FCCU
No longer applicable. Complying with final
Interim NOx 365-day rolling average,
corrected to 0oZ oxygen, from FCCU
No longer applicable. Complying with final
limits.
Final NOx 7-day rolling average, corrected
to 0oZ oxygen, from FCCU
lQ 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.23Yo of the
calendar quarter, as detailed in quarterly report
submitted 4130124.
2Q 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.05% of the
calendar quarter, as detailed in quarterly report
submitted 7125124.
Final NOx 365-day rolling average,
corrected to 0o/o oxygen, from FCCU
lQ2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.23%o of the
calendar quarter, as detailed in quarterly report
submitted 4130124.
2Q 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.05% of the
calendar quarter, as detailed in quarterly report
submitted 7125/24.
Final SOz 7-day rolling average, corrected
to 0% oxygen, from FCCU
lQ 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.23%o of the
calendar quarter, as detailed in quarterly report
submitted 4130/24.
2Q 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.05% of the
calendar quarter, as detailed in quarterly report
submined 7125124.
15
CD qI Limit Exceedances
25 Final SOz 365-day rolling average,
corrected to 0% oxygen, from FCCU
lQ 2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.23o/o of the
calendar quarter, as detailed in quarterly report
submitted 4130124.
2Q2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.05% of the
calendar quarter, as detailed in quarterly report
submitted 7125124.
28 Interim SOz 7-day rolling average,
corrected to 0%o oxygen, from FCCU
No longer applicable. Complying with final
limits.
28 Interim SOz 365-day rolling average,
corrected to 0oZ oxygen, from FCCU
No longer applicable. Complying with final
limits.
32 1.0 pounds PM per 1000 pounds ofcoke
burned from FCCU
Not applicable. Holly is subject to stricter limit
of0.5 pounds PM per 1000 pounds ofcoke
burned from FCCU.
JJ
36
37
0.5 pounds PM per 1000 pounds ofcoke
burned from FCCU
lQ 2024: Emission Limit exceeded,0.09% of
the calendar quarter. Total downtime of the
CEM was 0.00% of the calendar quarter, as
detailed in quarterly report submi tted 4130124.
2Q2024: Emission Limit exceeded 0.05% of
the calendar quarter. Total downtime of the
CEM was 0.00% of the calendar quarter, as
detailed in quarterly report submitted 7125124.
500 ppmvd CO l -hour average at 0%o
oxygen, from FCCU
lQ 2024: Emission Limit exceeded 0.05% of
the calendar quarter. Total downtime of the
CEM was 0.23% of the calendar quarter, as
detailed in quarterly report submi tted 4130/24.
2Q2024: Emission Limit exceeded l.l4% of
the calendar quarter. Total downtime of the
CEM was 0.05% of the calendar quarter, as
detai led in quarterly report submi tted 7 I 25 I 24.
IOU ppmvd C0 365-day average at 0o/o
oxygen, from FCCU Not applicable.
46c NOx 3-hour rolling average, from 8Hl Not applicable.
46c NOx 3-hour rolling average, from l2Hl Not applicable.
46c NOx 3-hour rolling average, from #5
Boiler Not applicable.
46c NOx 3-hour rolling average, from CO
Boiler Not applicable.
46c NOx 3-hour rolling average, from #8
Boiler Not applicable.
46c NOx 3-hour rolling average, from FCCU
Feed Heater Not applicable.
76
162 ppm HzS 3-hour average, in fuel gas
lQ2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.00% of the
calendar quarter, as detailed in quarterly report
submitted 4130124.
2Q2024: No Emission Limit exceedances.
Total downtime of the CEM was 0.640/o of the
calendar quarter, as detailed in quarterly report
submitted 7125124.
1.6 tons per day sulfur, from SRp
Emissions are combined with one of two
FCCU wet gas scrubber stacks. A detailed
summary of these changes was submitted on
619116. The limit at each FCCU wet gas
scrubber is 0.05 tons per day for the combined
SRU tail gas and regenerator scrubbed flue gas
streams.
500 pounds SOz in a24-hour period from
acid gas flaring No incidents in period.
500 pounds SOz in a24-hour period from
hydrocarbon gas flaring
Report for the incident on 5ll3l24 was
completed 6127124. Report submitted on
7t31t24.
Stack Tests - Emissions Monitored Stack Testi
PM from FCCU Complete. PM performance testing completed
on l2l20ll2. Report sent to EpA ll}3ll3.
NOx from 8Hl
Complete. Stack test report submitted l}ll5l0g
to EPA and State of Utah in accordance with
NOx from l2HI
Complete. Stack test report submitted l2ll5l0g
to EPA and State of Utah in accordance with
NOx from #5 Boiler
Complete. Stack Testing completed 2l9ll0 and
retested 3125110. Stack test report submitted
4129110 with Notice of Intent.
NOx from CO Boiler
NOx from #8 Boiler Complete. Performance test completed on
from FCCU Feed Heater Not applicable.
77
Attachment A
SRP Summary Report
SRP Summary Report no longer included per notification submitted to the United State EpA Office of
Civil Enforcement on June 9, 2016 detailing the change in reporting for the Sulfur Recovery Unit
Attachment B
TAB Analysis Reports
BWON Samplad Wast. Steam3 and Reaultr
2024
3/28/2024 l:20
1/74/)O24 1l:21 EW.l.r I X I
I t/28/2024 11r22
B
N
oI 6/12/2024 l2:45 mT
6/11/702a
3 6t11/)O1A \2:47
oil 416-m6.4,
t
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Attachment C
Summary of BWON Lab Audit
No BWoN Laboratory audits conducted during this semiannual period.
Attachment D
LDAR Audit Summary
No LDAR Audits conducted during this semiannual period.
Attachment E
Hydrocarbon Flaring lncident Report
Flaring Incident Report
I of3
Brief Description of Incident: Multiple Unit Shutdown After Loss of po*".
lncident End Date: 511412024
Incident Type:tr Acid Gas (report due 45 days after end of event)
M Hydrocarbon (report due in next quarterly NSpS, semiannual cD and MACT reports)
M Excess Volume (report due in next semiannual MACT report)
M Excess HzS (report due in next quarterly CEMS report)
CD n59. Report due: 6127 /2024 (45-day),7 l3ll24 (Semiannual CD and MACT reDo,ls)
CD fl59.a. Start dates apd times (list all if multiple releases u.. rffi
Start Date Start Time End Date End Time
5/13/24 12:23 am 5n4t24 12:23 am
CD fl59.b. Emission Calculations for SOz from Flaring (round to ore d"ci-ul poilt1
Constants:8.44x I 0-s : lbmole HzS/379 scf H2S][64 lbs SO:/lbmole H2S][tor/2000 lbs]0.169: [bmole Hzsl379 scf HzS][l.0lbmole Soz/l lbmole HzS][64 rb sorllb mole soz]
FR: Avg. flow rate to flare during incident (scftr)1s9.902.1TD: Total duration of incident (hours)24.0concHzS: Avg. conc. of HzS in gas flared (vol. fraction. scf HzS/scf sas)0.003
Tons of SOz: [FR][TD][ConcHzSl[8.44 x l0-sl 1.0ER: Emission rate (lbs SOz/hour): [FRl[ConcHzSll0.l69l 85.5
CD fl59.c. Steps taken to limit the duration and/or quantity oasorrerniss.ions
operationspersonnelworkedtosafelybringdownaffectedu,i
minimize flaring emissions during the outage. Following the restoraiion oipo*.r, Operations
brought units back online, per startup procedures.
Root Cause Analysis (CD !i59.d. and Subpart Ja)
Details of
Incident:
Following a power outage in Substation 3, multiple plant *its *e.e upset una Irua to
be brought down to minimize emissions. Facility personnel then worked to safely
restore power and bring units back online, per operating procedures. During the
outage, and in the hours following power restoration, sulfurous off-gases were sent to
the flare system.
Sequence
of events
in reverse
order
Result..$qlfur containing gases were sent to the flare.
...caused bv- -Multiple units entergd a state of upset or were shutdown
...caused bv.,Power was lost to part of the facility.
..caused bv..Multiple breakers in Substation 3 tripped.
..caused by..A 5,000 volt feeder to Substation 3 faulted.
...caused bv..
Root
Cause(s):
The power supply to a portion of the plant was interrupteLafte. ", u*,*tated,
abandoned feeder line to Substation 3 faulted.
Flaring Incident Report
Force majeure? M No tr Yes
Significant
contributing
causes:
The 5,000 volt feeder line was not isolated *h"r@
project.
Corrective action required? EI yes
trNo
If no, explain
basis for
conclusion:
CD fl59.e. Alternative measures available to reduce ttre titetitrooO of u rec,rneoc.,
Air gapped and ground faulted feeder line to SrUstution t
Probable effectiveness : Good
Estimated cost: $0
Should an outside consultant be retained to assist in the analysis of alternatives? tr yes
Evaluation
of possible
: N/A
Maintenance: N/A
tr Schedule for implementation:Commencement: 5l13/2024ion: 5/13/2024
Measure 2
Probable effectiveness :
Estimated cost:
Should an outside consultant be retained to assist in the analysis of alternatives? tr yes
trNo
Evaluation
of possible
Desisn: N/A
tion: N/A
Maintenance: N/A
eted
tr Schedule for implementation:
Measure 3
Probable effectiveness :
Estimated cost:
Should an outside consultant be retained to assist in the analysis of alternatives? tr yes
trNo
Evaluation
of possible
Desisn: N/A
: NiA
Maintenance: N/A
Flaring Incident Report
tr Completed
tr Schedule for implementation:Completion:
CD fl59.f. Statement Identifuine Grounds for Stioulatea p"n.rttir.
((,) rl-^,,-,{-M None
for stipulated
penalties due
to root cause
E Careless operation
tr Failure to follow written procedures
tr Equipment failure due to failure to operate ard muintain equfrnent in
accordance with good engineering practice.
Defenses tr Force Ma.ieure tr Startup/Shutdownfupset
M None
fl63. Grounds
for stipulated
penalties due
to frequency
tr SOz emissions > 20.0
pounds/hour for 3
consecutive hours or more
and
tr Failure to act in accordance with pMO plan
tr Took no action to limit duration or quantity
ofSOz
tr Total of Acid Gas Flaring Incidents in rolling l2-month period >5 (N/A)
Defenses tr Force Maje,ure tr Malfunctio{r tr startup/shutdownfupset
fl64. Grounds
for stipulated
penalties due
to cause
reculTence
El First time
M Root cause was sudden, infrequent, and not reasonably
prgventable
tr Root cause was sudden, infrequent, and reasonaUtv preverrtaUte
E Recurrence: Root
cause was result of
previously-identified
root cause
tr Malfunction
E Recurrence, agreed-upon malfunction
E Recurrence, corrective action plan not yet completed
E Recurrence, root cause investigation still underwav
Clarification on first
time or recurrence:
Defenses
tr Force Majeure tr Malfunction
M Corrective action being developed
tr Startup/Shutdownfupset
tr Root cause of investieation oendins
CD fl59.9. Will/Did investigation take longer than +5 days? g No tr yes
If yes, when will investigation be complete and report sent to EpA?
CDfl59'h.Willcorrectiveactiontake>45days?uNo
days)
I
I
I
I
I
I
i
UIfu I DEP^RI MEIjTEF
i
l_
DIVISION OF AIR QUALITY
,.dttf$nctor
Apil 30,2024
Director
Division of Air Quality
Department of Environmental Quality
195 North 1950 West
Salt Lake City, Ul- 841 l6
UTAH DEPARTMENT OF
EI{VIRONMENTAT OUruTY
, r.)ii I rl ?-CZI
DIVISION OF AIR OUALITY
urAH DEpAR'rn,tu-rufbr
EXVIRONMENIA! QUALTTY
AUG - 1 Z0Z4
DIVISION OF AIR OUALITY
RE: Continuous Emission Monitor Report, l', euarter 2024
Director:
In accordancc with 40 CFR 60.7(c) and Utah Administrative Code R307-170-9, please find enclosed theI't Quarter 2024 CEM and Excess Emissions Report and certification declaration for HF Sinclair WoodsCross Refining LLC. The electronic report file was sent to Mr. Rob Leishman on April 30,2024 via e-mail. This report contains emission information from the Amine HzS, Crude Oz, North Flare HzS, NorthFlare Total Reduced Sulfur, South Flare Hu S, and South Flare Total Reduced Sulfur in accordance with40 CFR 60 Subpart Ja, and U25 FCCU CO, U25 FCCU COz,IJ25 FCCU Nox, U25 FCCU Soz, U25FCCU Or, U4 FCCU CO, U4 FCCU NOx, U4 FCCU SOz, U4 FCCU Oz, and U4NZ5 FCCU particulate
monitors that are required for 40 CFR 63 subpart UUU to delermine compliance with the applicableinorganic MACT standard. I believe the information presented in the report is accurate and iomplete.The following apply to this report:
l. For any periods for which hydrogen sulfide, total reduced sulfur, oxygen content data, or sulfurdioxide emission data, are not available, changes were not made in t-hi operation of the
respective emission control system.2. The required continuous monitoring system calibration, span, and drift checks and otherperiodic audits have been performed as specified, except as noted in the attached report.3. The data used to show compliance were obtained in accordance with approved methods andprocedures and are representative ofplant performance.
Hand Delivered
4. The minimum data requirements have been met for errors thal
noted in the attached repofl.
were unavoidable, except as
5. Compliance with the standard has been achieved during the reporting period except as noted inthe attached report.6. Except as noted above and in the attached report, exceedances were not concurrent with astartup, shutdown, or malfunction of an affected facility or control system.
If you have any questions or need additional information, please contact Matt Howes at (g0l ) 397-74t2.
HF Srnr;larr Woo(ls Cross Refrrtrn<t t_LC
1070 W 500 S, West Bountifut UT 64087
801 -299-6600 | HFSinctair.com
I certifu under penalties of law that, based upon inquiry of personnel involved, the statements and
information contained in this report are truthful and accurate, and are a complete record of all
monitoring related events that occurred during the reporting period.
Sincerely,p**^ S' .^'^"')s
Dustin Simmonds
Vice President and Refinery Manager
Attachment
Mr. Rob l-eishman (DAQ)
E. Benson (r) File 2.2.1
ec:
cc:
u'ar'E.*btu dh&tuBdh.rld&[e-mail]
i ll0AminePlant 1 2024t 2184 l:I t:::::::y , irl,o 2184
110 North Flareiiri3Ji,li i,1,'" ', i3i1 31il110 u25 FCCU :"^::, 2184;;r;;;"'";";, rxzs 'i","."n" 'o'o',rooonouuro iiil o,o ,""" ' ,
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#s[:r ri 'ffii
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333 il,Sj;" iA" e,sm,. Epa rieeb, y pm,o % ,;; ,;; ;i i::: iT"
:3:ll:*:11 :::itffil::e;;
il N;ilil; rff" ' yiiizllt !1i;s;"i ]iiffi ,,i tz" ,il]ffI;:3ii:$li5f i:a' ', yi;iiti:l iiiytyzt 12ppm 046 o n.st24t2o23) ;li;;;;; );ii:: .9^49 o o z jp"" I
:::lyliiiy i!3; i #1!; : ;l 3 3i Sl 3l33syi:33yso;31iY;;::qeeffiiil iiil ili i",r"," 9,1i ;r ; o ' 9r 9sooiulrccu p".ti"rrrt" i I 9991/:. [r ; o oi 0 0
300 Crude unit 6)
3,oiNorrh Frare lizs , I i;SSl; 3. :, i il qi il3ooNorthFrare ;R; '^;1i ] o 3 3 3 S3oolsouth Ftare lHli i I 0'18% 4 0L ; ;i ^rsoo id;ii,'; iffi ; I o'41%' s 0 ..*.rrrrrl ;l 3] 3l300ru2s rccu i;; i 0.0s% 1 siiiliiii:l! 13& i I ea1i, ; lr 0n.,,,,.,3 lt 3r B;sooiuzs pccu iNo; I , 0'27o/o' o el o.gassssise 2i o oisoojuzs rccu ];o; I r 0 ?l% oL 3i o.gasoasiss 2t nl ni;ili;;;$; l#' 21ty1 ;, ;i lJliiiiiii i, Sl :lsoo,uzs rccu li".,ricrrar. r i o'27oa, 6 ai o.nr....i5i ii ;i 3]eoo uzs rccu lplrti"rrut" r I 9 907" 0. o
31,rAmine prant rH2s r o ' 2'22!: i, ;l 3 3f Bi o,
ffitrl H iffiiiiil#m*sr-' 'uqFUUu panid'"r. ol xii6ir;n"o*zozrri-n""r*, i o. B 3i .rilffi," i:i#h,
310 U4 FCCU part
310'Crude Unit 02 ; Ot4% 0310 North Flare H2S 6 o )7o/^ 2 3 Oil;isl,?,?fl: l[i! , 6' oztii' ; ;1, ;' 3]ii, uii'icru ;6" 3 !!!tr s s, 3 33l3rUffF33U ilSX , er ooov" ; ;r o ol
310 u25 FCcu so2 9l o.oo% 6 ol o oiai; u;;;;;; ;; l, 9 991: o 0 ; ;
66 psi hourtv
5 ppm thourly0l
0
oi
oi
0
ol
0
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ol
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162 ppm 3-hourRA162'ppm lg-nour RA i
etoluzs rccu 'soz , or |.l|il 3, 3l o,
Bi
SO ppm 7-day RA25rppm r365-day RA
12.9 in H2O 3-hour RAglgig?s_lgcu iparticurate , ;l i.ilil: ; 3l g 9i410 u4 FCCU , lNone this quarter i o oi
+roluzs pccu r r ri.ll-I llil q""'1"'
420 rJ4 Fccu None this quarter
o.tgiGpMlMsig-nour Rl'l
;;;i;;;;ccu i lffi::llH:::fr i i430 Amine Plant il;;;;;;;ail;430]North Flare Ugt2O24 20:00
430 North Ftare 3tfitzo24 ]O,oooio r'i"il,.il" ena,ioiq ,.,,00 )1?:l i313
111 yll Il"* 3t1at2o24 22oo iai i ;;.; ;430 North Flare il18t2024 23:00 iiA.8 ;;; ;43olsourh Frare r -"-'-"--l 'o "i.,--- ^,-, ^i;9i;ftil'" : trnrzozqr .,,ooJ*onu this Qua(er ; ;;; ; I440 U25 FCCU None This euarter470 crude unit 1t.t21.797+i 2:001 6.4 zosio i l470 crude unit I tnttzozqj ;,ili s.1. 703 o , l119 g'.rg: y"it .urttzoia 4:00 s.4 703 o4eo u4 Fccu 2t2,t2o24 i,fi oi.o ;;; ;l::iyij::: i iii,[oiit i,ool s24, zo3,N i
l
l
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l/OO, 701 Startup/Shutdown ,
izooT 702lcontrol eqriomenr probl.rn",v. vu,uur Equtpr,ent rtootems I700 ZO3 process pioLl"r"
199r zoaiotner Known causes i I700. Tos,Unknown Causes ' I I
500lppm hourty
80 ppm ,7-dayRA40 ppm 365-day RA
UTA
DrvtstoN oF AtR OUALTTY
l?r^ iii il."t", Equipment Matfuncrion
!20 722 Nonmonitor Equipment Malfunction720 723 eA Calibrations720 724 Olher Known Causes720 725 Unknown Causes730 701 A 'plantwide poweroutage.730 201 B pr*"r. .,""nrprshutdown in other units causing upset1?9 701 81 icCul#.g" p,;;;"i;;;;;;';;Ji,n,,.n,,oo*nl:o^ 7_01 ?? unit 20 srart ,; "J."J ;il;;;;;;;""rru 701 83 Upset in Unit 21 caused hilh H2S in Fuel Gas
,33 i|o1 z' . lnterlock in unit 17 caused-htsh Hzs in ru jtas. brousht unit back ontiner lunit shutdown due to Gasoil leak!5u 701 D Start up/Shut down730 701 E 'FCCUi""J"r"""J"dpr...rr"timitandcausedunitshutdown
!30 701 E1 FCCU btower faiture causing unit shutdowi119 701 F startup/shutdown of FCCU
::y 701 G Turnaround of SRU and Amine Unit/30 701 H Unit depressurization caused excess flow to the flare1?9f zot lt iOz St<io shutdown, resutting in combustion issuesa:2 7_02 | conr,or elripme"it""ii"g "
!3U 7O2 B ,Control equipment failure-, replaced equipment730 702 c .Faulty
sensor resulted in control problems. ,nit
"ontt.olt"o manually119l tozlo iBreaker/transformertrioDedcausedunitorr^dean.ray^a-d.^^^ o^^^.^.tuz u Breaker/lransformer kipped caused unit outage and exceedance. 'Reset and attempted to line out units730 702'E Jlnstrument controller filled with water due to water in plant air. controller was replaced730 702 F iPro"ess control problems led ro variations causing upset. Attempted to line out process varialions1:2 ,_2? ?, C"",r"'ir;" Intertock, atrempted to bring unit back in tine
rvv^ev uP, r EJEI uu[(ruIcIl3o 702 I lExperion lost communication, attempted to reconnect l
119] zoaln iil;;; worked to bring power back ontine and tine out units l730 zoe etlo ,n",,n lProcess issues in otherunits causing upset. Attempted to tine outprocess/uJ u Process feed problems led to excess emissions, attempted to line ouireeo.730 703 D nug"n .liJu "rlre issues casued unit to swing
i'r|t l:li: i:d.",:" r"ii"tion. caused emission excess. Made adiustments ro unir to brins back in tine730 zoe r unttini"'lo"t. caused high flow ro the o*", *"11"0",X?HilT[:"J:il:,bnns back in73ol zo3 H i;;;;'ffir*kof theFccu,Atrempredrestarrof unit l
f: 191 | x"","ri"i"ril"* Boughr Hearer back ontine.
;;: j:: j. Compressor tnrertock, Compressor brought back ontine/ur K Lost charger to unit. Brought unit back online lz:ol 703lL ixigl' Hii'i;fr"r gas releiving to flare, attempred to rocate point and crose rerief varve119i zogi[4 iunit 17 Thermal reacror shutdown, worked on bringing unit 17 back online130 703 N Plugging, worxed to ctean out tine730 703 o ]pr.i ttip "aused proces" swings, worked to bring pump back online l
Ii:i 19:ll Compressor overwhetmed causing unit upset l730 zosio ARN issues r"a ro nrr" .*iorrrl rii.i"lirn Hzs1191 tott,a, lr,"iriii pl"J", uru.i-ort7301 704 B Calculation error in performance test data, controlling to incorrect limit::2 !y1 g uaintenance work tripped FCCU interrocks
urrrrurrrtrs tu rlrcorrecl rrmll
t 5u 704 D Purging of vessel t"srlted in excess flow to tn" flur", worked to control flowratezgo I zo+lt FCC lntet Vatve Faiture730 704 F si"lk;t.rb."r,on tripped, excess flow to the flare. units brought back in linel:2, I91 9 nerier varve rirteo, ,"iIJi"r"J r"i;;;".ii8 i317,'. i*i:,1fi,x[Lliffi,Tii:,:"._[?l::,,,u::*::* nare now subs ded122, !91i' i;;;-il;;;diti"nins issue r::i !20. l. Source Tesring for timir dererminationjflf :: f iperformance test timitarions, adiusted process parameters l
ffi i3;,,:" Live Flare work resulted in excess H2S emissions. comptered workii;i ;;;1il liiilTiilh[l,l,:]:[l,xJHfffilri:::lti;:.T:T,l:?"',"j,'ll!..",,",,"p",,730 704 o Hign amiient temperature caused lower flow rate, worked to lower temperature119, l0!1A iunt<nown ""rr".
'- l- - wul^eu ru rower tempera
i730 705 B Hi^h Hzc r^ a^.^ ,.^L^...-a1^ ,High H2S to flare. unkown source. Search tor source conductedl:Y tzt ,A Daily calibration check exceedance. Recalibrated instrumenl.730 721 A1 Fccl I rl2 ^n.t\o6r A-t^,^.,^,,, -^^^;,---;- -
L
i
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ll
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lili 'r;',t,i) ]ffi":#:::f::*:1,:::,11.^L:.::ribrated instrument. carcurateo data invaridated due to dependence on 02,"a",,'u.J,unr::X) !?1- l'? iDaily Drift not performed due to power outage. rr rvorrudtvu uue to oepen(tJU 721 B Datarecorderfailure. Performedmaintenaiceonanalrzer. lz3o' tz.ric i;;",. rr,;;;. r
::2 '-?: ? cD failed. U-nscheduled maintenance performed tnstrument recatibrared.r z t tr Loss of sample flow. Flow was restored730 721 F enaiyzer erobe faiture119] lZ.tiO Broken part inside anatlzer, part reptaced730 tzt,n i:::Ii: i:::"*,::lir: ry*,* ,
zoni _:.r:. lBrokenpartoncalibrationgassystem. partreplaced i
::X !:1 ,. Anatyzer end of tife, Reptaced anatyzer..
::: !?1'l Anatyzer tocked up, rebooted Anatyae r l/JU 722lA iLeak in monitor sample gas line. I1191 722',8 ,sampte System Contaminated. System Cleaned Out]llf !1?',9 iAnalyzer Software ualtunction, nlsei;;ft;r"
t:X :::)! llnstrument Air down, not able lo actuate sotenoids and vatves1:: t zz\E lssues with sample conditioningt3o 722 F
iig i i;;t; l[l'|:flJ..:[* ;:]::#J"" red to rockins up or anarvzer Repraced crimate contror i
730 1231 A1 rccu oi unayoer data invalid. calcurated data invaridated due to dependence on oj measurementl3g 723 B cyino", cffi aroir:22t !?4.)! ;r1,,*.i',"r,,i"J"'"..i r!?O 724 B Annuat preventatir" Muint"nrn""190 724 c ruonitor rept"cement130 724 D .sampte
"y.r", ,.fir""r.nt
f:l ,_11t1 e,,rremeloro weather caused Refinery Wide upsers
730 tz+lc is".pi" svli"rn Mainlenance
HFS CEM Report 2024 .le _ ASCil RpT 2ot2
,.dltf$nctotr
July 25,2024
Director
Division of Air Quality
Department of Environmental Quality
195 North 1950 West
Salt Lake City, UT 84116
Certified Mail: 7019 I 120 0000 0070 9245
RE:Continuous Emission Monitor Report, 2od Quarter 2024
Director:
ln accordance with 40 CF'R 60.7(c) and Utah Administrative Code R307-170-9, please find enclosed the
2nd Quarter 2024 CEM and Excess Emissions Report and certification declaration for HF Sinclair Woods
Cross Refining LLC. The electronic reporl file was sent to Mr. Rob Leishman on July 25,2024 via e'
rnail. This report contains emission information from the Amine HzS, Crude Oz, North Flare HzS, North
Flare Total Reduced Sulfur, South Flare HuS, South Flare Total Reduced Sulfur and Sulfur Recovery Unit
SO2 in accordance with 40 CFR 60 Subpart Ja, and U25 FCCU CO, U25 FCCU COz,U25 FCCU NOx,
U25 FCCU SOZ, U25 FCCU OZ,L)4 FCCU CO, U4 FCCU NOX, U4 FCCU SOZ, U4 FCCU OZ' ANd
U4N25 FCCU Pafiiculate monitors that are required for 40 CFR 63 subpart UUU to determine
compliance with the applicable inorganic MACT standard. I believe the information presented in the
report is accurate and complete. The following apply to this report:
1. For any periods for which hydrogen sulfide, total reduced sulfi.rr, oxygen content data, or sulfur
dioxide emission data, are not available, changes were not made in the operation of the
respective emission control system.
2. The required continuous monitoring system calibration, span, and drift checks and other
penodic audits have been performed as specified, except as noted in the attached report.
3. The data used to show compliance were obtained in accordance with approved methods and
procedures and are representative ofplant performance.
4. The minimum data requirements have been mel for errors that were unavoidable, except as
noted in the attached report.
5. Compliance with the standard has been achieved during the reporting period except as noted in
the attached rePort.
6. Except as noted above and in the attached reporl, exceedances were not concurrent with a
slartup, shutdown, or malfunction of an affected facility or control system.
If you have any questions or need additional information, please contact Matt Howes at (801) 397-
7412.
HF Sinclair Woods Cross Reftning LLC)
1070 W 500 S. West Bountiful UT 84087
801-299-6600 | HFSinclair.com
UTEU orPaR rMENT ol-
E NV r R o Nl M E N-rAL_-qlELl-lY
DIVISION OF AIR OIJALITY
I certi$ under penalties of law that, based upon inquiry of personnel involved, the statements and
information contained in this report are truthful and accurate, and are a complete record of all
monitoring related events that occurred during the reporting period.
Sincerely,
P^LS,n^*-*A
Dustin Simmonds
Vice President and Refinery Manager
Attachment
ec: Mr. Rob lrishman (DAQ)
cc: E. Benson (r) File 2.2.1
ffi
110 U4 FCCU 2 2024J 2fi4' '. i
rro c.o" unir ;' ;;;;l ;;;; L
'llo North Flare ; ;;;;' ;;;;' I1'10 South Flare 2' 2024 , ;1B4l 1 i .rto uzs rccu zl zoztl 2184ttolsrttu Recovery Unit z' zozqi zteq2oo Amine Plant H2S 'siemens 3004945670 oolo 3oo ppm 4t1t2021 FuetLine
!!!lya 199u co lreredyne Monitor Lablr3oo , saoal 1ild;;, srioiioiilit""*200 u4 Fccu co2 iTeledyne Monitor LabiT3oo uoqi o.2 5/30/2021 istack200 u4Fccu Nox iAmet"x ,1s99nu seoo-s16i6-i . ,zoopp, ] zrir-oieisu"rzoo un rccu so2 jrenoyne Monitor LablTlooH 1 qatt, - izoo pp, 5/30/2021 Stackzoolua rccu .o2 iAmetek seooRM lggoo-sroro-r zo;/." - iri:riozilso.xzoojua rccu parricutate lRosemount ]sosrcozezzarasresuso,.zzzaoto l- rctzt:tzoiilse"x200 U4 FccU Particulate Rossmount eostrogA2e2lAstesuso.izzzezso , .- ', iot2tt2o1?)stack2OOlCrude Unit 02 ilmetex Thermox wDG-tV 102086s6 - 2oo/^ | 'i,,i):iiii''"r"",200 crude unit 02 Ametek .Thermox WDG-IV .10208656 ZOo/. B/17l20.t5 Stack2oo NorthFlare H2S Exlrel Max300-RTG 62582 ioopp, rlaiioii rrrr"t-in"200 North Flare TRS Thermo Scientific Sota l si-ogloogra 2000 ppm ,o;/"" ti,,t\,iitii Ftare Line200 South Flare H2S . Extrel Max 300-RTG 62585 i6o-pp, tt,s,,ioii Ftare Line200]southFlare TRS Thermoscientific ,sotalt isL-oggzost+ i zooopp. 30% lt?t1/zotslrtareLine200 U25FCCU .CO stcK McslooE ltsoozszs I 1oooppm i Or,ZOrOistack
?99 y?! l99u ,co2 l9!9^ ,r,,lcsrooe rsooze23 I izow I orlzoroistacx200 u2s FCCU Nox l:!9K LMcslooE lrsooz:za I - lzoo ppm j orrzoroistacr
?99.y?! I99y ,9oz srcx racsrooe rsosis2s itio il, ' 6/1/2o16istack
100DustinSimmondsHFSinclairwoodscr(1o7oWestsoosoiittwei
11O Amine Plant Zl ZOZL 2184
2001u25 Fccu Particutate lRosemount ]rosrcoaazzernsriasrsq.'gosrco+A2zau eilioio """*200 U25 FccU Particulate Flexim/SlcK Maihak ,US-7407/S|C 199 .F7o4t1so62323 stzOti}ti Sta.x220 Amine Plant H2S I 1 5t1t2o2al I -'-- -- i220 Amine Plant HzS Sl1l2O24
iilrliiilU*'" iia" ',, 0,,,,,0,0,1 ,, *]"-''l';i;3r;l 21:set ,,]o, j*"
)rd I ti cfrt I ^nt2201U4 FCCU .CO2 . None this euarter izzolvq eccv Nox at'tvzozt] 21 :00 qi,tatzozqi 2 r :591 t23', A.t iro220 u4Fccu 02 q,ni,i&+ ,i il iiii,iiq ;i,;; ;r;i; No22o)u4 Fccu so2 , 4t1gt2o24'. 2.t:00 4rtgl2o24 2,t:59 tii x No22O U2SFCCU CO 4t24t2024 6:00 4t24t2024 6:59 723 A No220'u2s Fccu co 6t2ot2o24 a,oo a,io,rioiq ;,;; ;;;; No220 u25Fccu co2 4t24t2024 o,oo itii,rioi+ ;,;; ;;;; No2zo u2sFccu co2 arzotzoul eoo o,rzorioia a,;; ;;;'; lruo220 u2sFccu Nox . 4t24t2oz4 ;,il irii,tioi+ ;,;; ;;;; No
??9 U?? F_ccU Nox 6t2ot2o24 9:oo 6t2otzo24 9:59 723.8 No2-29)y.?1199u 02 t qrzqrzo2q', 6:00 j uzuzoz+i 6;5e' ntla ,ruo220 U25 FccU 02 6l2ot2o2i q.oo i ^tzfitro2l o.qo a.1 a l^'^220 Uzs FccU 02 't 6t2ot2o24t 9:00i 6tzot2o24, 9:S9i zzaiA lr.ro22o u2s Fccu so2 arzatzoztl 6:00 qrzqriozt ;,;; tiit i No22o uzs Fccu so2 6tzot2o24 , il arioirr.q ;,;; ;;;t; No220 Norrh Frare H2s srrztioit ;,il lnqi,tiitii ,i,sg ;;;l; yes
220 North Frare H2s st3ot2o24 . ro,oo i,rzirioz+ ;,;; ;;; i Nozzo I No.th Fr"re H2s ' arzs,riozq s:oo i,tiai,ioiq r i ig ;;;; '"o22olNo.th Frar" nzs i, atzarzoz+ riioo oii:ri6iql ;,;; ;;;; yes
22o North Frare rRS ' iriioiq', ii,ili -;;;;;; ,;,;; ;;;l; No220 Norrh Flare TRS St23t2O24 10:00 St23l2O24 ZO:SS tii A NozzolNortn Hare rRS .. 6t14t2024' 15:oo i,noioit ;;,;; ;;i; 'r".220 soulh Flare H2s 6t26tzo24'. i1:00 6t27t2024 9:59 tiq'B Nozzo;srutn rtare lry: 9,.?9,29?4 i1:001 -ditit:rioi+l s,is1 ;;;i; il!.
:391:"yth Fj* L!! arzarzozql 11:oo 6t28t2024" 1.1:se 72318 ir.ro
260 u4 Fccu ;o i'ris,ioil )ZZ;IZ;62 Z:i?,;ZtZZ;i +;3:::iliil;::[ i3il ':^?l 3i3 3 ] 8 Slii riiX'^ rzoolu+ rccu co2 si'r2i'r26iqt ;iili;;;; ', gi,iii"oii,ifa r,,"""oiiiii i,,"i.];zl' -i J -;.;l i;10,"" r; i260 u4 Fccu co2 3t2st2o24 z cizsstot 6t22t2024 EpA Traceabirity protc o/" tt i ti o ,.r ;::: . r"i}r. I260 u4 Fccu Nor 3t26t2o24 f iiiioqis ii;aii'is i;; i;;ffi;il;;;i. fu ;1.; i6.i ,i.n 0,.. row I260 u4Fccu Nox i,Di,ioiq ;;;;;;;;; d,iil;; il;+;ffiilili:ffi ,ili ,i\; 'iu 0",. h,shr2oo luq rccu so2 3t26t2024', tlccitoili l, ii,,ifioinilpn rraceabirity protclppm , 50.6 50.4, o.4lpass rrow Izooiua rccu so2 I, st2at2ozq z c6,+tiz6s ;;;;;;ili;pA rraceabirtv pror. onm 11n A 11n ? n al^.." .rr^x
Iiioiui iccu ;; t, ";1i2fi;i11 ;lZZ;tZ;62 t:;;:,;i;Zi1;i+I3:::ilfi;[[]3ll I ,?33 ,?3i 3ii33li i"'}^zooiur rccu 02 ' trzstzoul r,gcsiriiii "ti,i:rioiill;ail""""iii-ib,"ii;:'/ I ooi s.ol rr.i]i"., lffi'260 u4Fccu 02 s,tii'ionq z eediade3o sbr;;;1r=pArraceabilityprotc% il.o 11.1 .t.1 Dass h,oh260 crude unit 02 i,ioioic i ffi;d;;; 'tlii,ioi, i"orraceabirity protc % '3.; ';.; .., ,".. roiv26olcrude unir 02 srcriocq, ,i"91919?9 ', .?.?gt?9?ltl;;;;;;;;il;i;;;i.lt; ;.;: ro.i ;:l;::: ];1}.260'North Flare H2s t 9t.?9t.?o^24'. ilcczrorra ttngtzozsiepA Traceabirity protclppm 58.9 s9.5 .1.0 pass tow260 North Frare H2s 6t28t2024', z"icioioti iit)oirii,iilipA rraceabirrty prorcippm ,i!.r. ,;;.; | ].i]ilii l^T^3:: li:11:g: H: ariaioiq' ; ailieie; ";;;;;;i;;i;;;;i;i;;;i;ffi 4550 4046 125 pass
'ow?991I"11 !1"* Il! 6t26t2024' 2 cc456684 stzzozs epleri"."oiiiii p,"iilfi, 1348 3 11sz.o 1. i ffi. ;i;zbu Nonh Flare TRS 6126t2024_t 'l SG9'I463878A1 gt23l2o24 Pimary Standaid ]pp, 63782.3 59970.0 6 4 pass r.i,
?99;ynl ll."* Il! arzatzoztl z ccisois- -"- s1,,71:,1oii certined standard-sprppm rizzii.i ,ioiiro.or i.ililii ^";260 south Flare H?! 612512024. 1 cc2'16'113 'l1l2gt2o25 EPATraceabitiry protc'p;m il.s sg.i s.a lr.. ;;;260 south Flare H2s 6t2512024'. ziccsoqo'tt ', ttzotzozsiepA Traceabitity protclppm ,tsz.z' i1.i ri.ailr.. ;';;26olsouth Frare rRS i illi:ir"i::, tiqgtqgggn ', ini'ioiilipA rraeablty protclppm ; +io.s +oa.oi ; ;l;::: ffi260 5qu16 pl6tt rRS atzetzou.i 21cc456684 aruzo2s -pA Traceaulityprotclppm ,, ela.o' rio,j.oi i.i10".. lhigh;:: :::ll:i::: H: 9t?gt?o?4. r sgsr+oiizenL ghirioii)irimary standard pp, dil;.; u;;;.; i.u 0",. rowzou uoutn Flare I RS 612812024 2 cC55059 5117t2O26 Certfied Standard SPI ppm ' 't82902.3 ISO1OO.O' 1.6 pass ,high260 u2s Fccu co oioi,ri6zq i 6q1191i: \;!i1;^;;;;pA rraceabirity protc ppm 246.5 24s.o r .o pass rowzooluzs rccu co 't Gt2et2o24 i icir.azse srrorzosoiepA r;;;#ii;;;i;1ffi iji o isg.i i.o p"r" hish
?99 y?:I99y 99? atiotioiq ;;;;ii;;; g,i6iiozi;;;i;;;;;;iil;;il" -;; -;; il;",. i;;260 u2s Fccu coz arzorzozql 2,cc2ss7o1 a,piioiqlien ri".""uiiiii e,"ii;,i" | ,tz.n ,rz.ol ,;]ffi: ]il;.260 u25Fccu Nox oio,Eoiq' i;f\i:li \:1tr;/iri;;p^r,aceabiriryprotcppm ;..; #.; i.l',.. row260 u2sFccu Nox aioioiq. iiLqtazgg srrorzogo ep;i,;;;;ilF;fi; i97o 111.2 3.8 pass ,hish199iy?:I99y :9? ' 9rz9rzo1+.1 rl9c+z6rii ' ;:ta;;;;;l;pArraceabirityprotclppm I sr.o so.4l r.2 pass i6w260LU2sFccu so2 6t2ot2o24 z ccsrsrao stzarzoztlrenrraceaoirityerotcjiim rrs.zl 118.01 .;];;; l;;;;260 u25 Fccu oz 6t2ot2oz4 , "?:ll1f s;?:i^!aga4 ipa r,""""iiiiii i,i"i.lil s o 5.1 2.2 pass
, row260 u2sFccu 02 i'tioi,rioiq ^^-^i Iisoogoo ststzoz4EpATraceabirityprotclo/" 1,1.1 11.0 0.3 pass high3oo Amine pranr H2s 0.640/0 ,t4. "'"'-"-, -' '-iils-dil.iiil '" o o o
2soiAmine Prant H2s 4t3otzo24 ststiiis - --]? *- -- i;.;',- .,n.ri''" t.alpass , . i::g yi :g!y 99- st1t2o24 sntioiz l? pp. gi Cn nili 2 o pass
::g y1 I99y gg2 st,tzoz4' st4t2o23 12 ppm -ia g i;;j 2 4 pass2so u4 Fccu Nox st1t2024.. st4tzoz3 riiii tt.tzl ;;.;; 8.6 pass?!9'y1I99ySo25t1l2o24s'tq,Doii,l2ppm;-q1];;;;;';ffi250 U4 FCCU 02 5t,12024 st4tzo23 ,tzit" 1.86 2.69 0.8 Dass250crudeUnito28t25l2o237l15l2o2213ppm32.7rz.si"..
250 Norlh Flare H2S 312612024 3t,13t2123 12 ppm 2.2T O' 3.0 pass1:91:9:tlfptg !?s stztrioit\ ii,i,Doiit i;Iil; o;;l 6 0., 0"..250 u25 Fccu co ', gt.z^u.7972i anzrzozzt reipp, ', ,rsz.tl, rsz.si 1 5 oass izsolues rccu coz erzqtzozsl t:nizozi 13 o/o 13 14.3 l; ii#:: I
::9 y:::g9y !9t . Etz4tzo23 a,nzioiz ;, ;;^ ,r i ;;:.; ;. ;il2s0 u2s Fccu so2 st24t2o23 7t12t2o22 ]l,p.p. 1.2' o z s]ir..2so u2s Fccu o? Bt24t2o23. t:yiiiii 13 o/o ;.;l ..i 6.s pass260 Amme Prant I29 3t27t2o2.4. - -j ggt:11 4t'tst2ozs EpArtaceabitity eili. pp, si.i "'"" sg g 2 3 pass .tow260 AminePlant H2s I ltzttzo2q 2 ALMo56oo6 4t23t2024 EPAlraceabitityprotclppm i ta.z, 1z8.iL o.llpass high:::l*:::l.l :: y1:7yt:t ;r;;;il;;- ;:,;;;;;;1i;;iffiffi;;;;ilffi t, ,o,, 24eo 1 3 pass ,ow
ffi il;ffti"' ;6" 331"i: '1 o 13e83333331 ? 3 3t99y1l99y 992 ;;;;;; i ; ; I o o3oo u4 Fccu Nox ; #;: I X X, : "gootu+rccu so2 ' ' I9i1:i tI o' ol I o ol
199y1lg:y parricuate 333il ; 3 3 ; S Sffir!l,::i[, Particurate , 9 991:i ol oi gl gi o o i '
:ee l"il# ri: !,i!i; ,ll ,i leeereree3] 3 ,;] l
'
300 Norrh Ftare TRS 2.65o/ot 58i 46. 10.98333333 1 O 0
i3S::::il:iffi ii: i:::il ;i -s """"""""[ ? ,:
s3oo u2s Fccu co- I , oosy" i 9i ;] ;] Ii IL I ,
3OOU2SFCCU COz o.o9% 2 O o 2 o offilU;:F88U |3; eerl:, ;i o o , z' ; ;
aoojuzs rccu 02 I ; 9 9?1:' 2t' o' ;l ;; i, ii i .
1999?199y parricu,ate 333il 3 3 3 3 3 S3ffirxi:,'""#, Particurate i 9: BBB:fi :l g si sr s: ,u8iro* jr***l3loiAmineptant .. lt: T 6l o.oov" ;. .] o] ol o1 iolil, 36s_day RA1l9l:.lrf:ll::'*ry un,r.so2 9l q qqf , oi ot or oi oL loolppm 12-hour RA310 U4 Fccu co zSt 1.14o/.,, r I o 24 ol o] Soo]pp, ;;;r;; 'J
srolu+ rccu Nox ; ;;i"1 ;i ; -o ; o 40 ppm l7-day RA
119 y1 f99y fo' : q:991i i ; ;l ; o zzs ppm 365-day RA310 U4 FCCU SO23iou4Fccu so2 0 000% 0 o 9 o o so]ppt 7-aav(Ao o.oo%: ol o o o, ; ] ;]ffi ,36s-day RAatoiL,4 ps6g iParticulate i o o.oo,i,"t ;i o' o; o; o q 2 in H26 hn,rh,I rru u4 FUUU Partrculate 0 0 ooo/' o oi gi o o s.z in nzo inouay
'I oto u+ rccu parricuiate I i.ii{ ; ; , ;l ; H ;:l' hourryi 310 crude unit 02 o o.oo% o 0 o o of "i I* hourty| 310 North Frare H2s 6 o.z7o/. n o ; o o ,1ui I[, l]i",], *
I iliiliiifli Ii' i, iiffi s s ; s; I *:iin ;,l:lril ii ::l y::t::y 19, o ooov" ; ; I o o aolcn. 7-dayRA II 310U25FCCU Nox g gggl o o 0 o o 4oppm 365-dayRA II sroluzs rccu so2
| ::l y:: r::y :o2 3 BBBI: B B B; B; : ::ll* :l;f:j,,il^
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I4201u4 FCCU
420 U25 FCCU
430lAmine Ptant
430 North Flare
nSO]ruortn flare
430 Norlh Flare
csolruortn rAre
430 I North Flare
430 I North Flare
430 South Flare
430 South Flare
430 South Flare
440 U4 FCCU
440 U4 FCCU
440 U4 FCCU
4t1it2o24l
4l'17t2024
4t18t2024i
4t18t20241
5t14t20241
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411712024
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173.2
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187:2)
233.6,
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4356
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5061 I
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6845r
5882
4772
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5187
5200
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5087
4754
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3898
3853 [
3718
2333
2e84 I
26241
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2316
553 I
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l64.9
440 U4 FCCU
4401U4 FCCU
440 U4 FCCU
44olu4 Fccu
44olu4 Fccu
440 U4 FCCU
44olu4 Fccu
440 U4 FCCU
44oTu4 Fccu
4401u4 FCCU
440 U4 FCCU
44olu4 Fccu
laolua pdcu
44olu4 FcCu
440 U4 FCCU
l440 U4 FCCU
44oiu4 Fccu
44oiu4 Fccu
44olu4 Fccu
44olu4 Fccu
44olu4 Fccu
440 U4 FCCU
44olu25 Fccu
470lCrude Unit
49olu4 Fccu
490 U25 FCCti
Tool
7oo
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7oo
700
7201
4t17t2024
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701 Startup/Shutdown
702 Control Equipment Problems
T03lProcess Problems I
704 lOther Known Causes '
705 iUnknorn Causes l721 Monitor Equipment Matfunction
722 Nonmonitor Equipment Malfunction
723 QA Calibrations
724 Olher KnoM Causes
T25iUnknown Causes I
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7201
720'
720i
72ol
730
730 I
730 l
730 I
73ol
730 i
730
73ol
730
730 l
730 1
730 I
zso I
7301
730 I
zao I
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730
730,
730 If30l
7301
730
7ol iA
7ol lB
701 lBl70't 82
701 ] 83
701 84
zor ]c701 D
701 rE
701 iEl
701 lF
701 ic
7ol lH
7o1 l
702.A
702.B
702 C
7o2lo
7o2lE
7021F
702 G
7o2lH
7o2ll
7o3lA
zoaie
703 C
7o3 D
7o3 E
7o3 F
7o3lH
7o3it
703 J
703 K
ToaiL
703iM
7o3iN
zoe [o703 P
7o3lo
704 iA
704'B
704 ic
704 D
7o41E
704]F
7o4lc
704 i G1
7041H
7Mt
704 J
7o4lK
7o4tL
704 M
7o4iN
7041o
705 A
TosJB
721iA
721,,A1
721:Pc
721)B
721 C
721iD
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721 G
721 H
721]1
721 J
7221A
722]18
722 C
7221O
722 E
722iF
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7nl,A
723 A1tz:lB
724;A
724i8
724]c
724'tD
724:E
724iF
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i
Plantwide power outage.
Process siartup/shutdown in other units causing upset
FCCU charge pump lost flow and caused unit shutdown
Unit 20 Start up eused high HzS in flare
Upset in Unit 21 caused high H2S in Fuel Gas
lntedock in Unit 17 caused high H2S in Fuel Gas, brought unit back online
Unit shutdom due lo Gasoil leak
Start up/Shut dom I
IFCCU feed exggcdqd pressure limit and caused unit shutdown i I
FCCU blower failure causing unit shutdown I
Startup/ShutdoM of FCCU
lTurnaround of SRU and Amine Unit .
] Unit depressurization caused excess flow to the flaie I
loi siii''r'rlo* ,;"J!!t,;, ";;b,"ii""i;;,"1-'- i ]
qonlrol valve interlock attempted to Uring unii biik tn line
'controllerlockedup,resetcontroller"_-_,.LExperion lost communication, attempted to reconnect I i
]Power bump. Worked to bring power back online and tine out units I
]Prmess issues in other units causing upset. Aftemple to line out prbcess I
. Process feed problems led to excess emissions, attempted to line out feed.
1
1
l
' Control equipm€nt testing
I Control equipment failuro, replaced oquipmont
l rrrqy ""i.o. r".r["0-i" "o"iroi p.ulems, unit controiled manualy i
I Bra4ker/transformer tripp€d caused unit outage and exceeainCe. Reset and attimptdd to tine oui units
llnstrumenl controller filled with water due to wateiin plant air. Controller ms rsplaced
. Process control Problems led to variations &using upset. Attempted to line out process variations
. Control valve interlock attempted to Uring unii Uiit< rn line i
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730
730
730
730
730
730
7ro
730
I
730 l730
7301
73ol
730 I
73ol
730'
73ol
730 I730
z:rol
730 l
zso I
730;
730
7301
730]
730'
730'.
73qi
7301
7301
730 l730
730
73ol
7301
730 l
730 I
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730
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730
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730
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73ol
730 I
73ol
730
730 i
73qi
730
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730 I
730l
730 I
730
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I-- Ulnnt FH\4]ROlA^rr rslulr rcu ru ildre scar ututlts loeraUng nZD I '--','_]]:_-]Facirrtypowerbrack-out , i I i 1l I ircqlgulqtion error in performance test data, controlling to inconect timit i i I ! I I
iMaintenance work tripp€d FCCU intertocks i Ip;,s89;i;;".;;;J;rr"!-"-;;;',r*i"o,n"n"/",workedroconrhrorrate i ] ]l lrAtlG
. Calculation error in performance test data, controlling to inconect limit I I,Maintenanceworktripp€dFCCuintertocks , _ . i I ^1n]Purging of vessel resulted in excess flow to the flare. worked to control flilrate I | -'\ I ttl
lFCitietvatveralure -l I ] I I I]Breakersubstationtripped,excessflowtotheflare.Unitsbroughtbackinhn€ , I I
Relief valve liffed. valve conected itself before being tocated I]ii;i.-;i;;;;;;;;;'". Knockourwasdrainedandflareflowsubsided I I nr',/lSlON (
lsampleConqitioningissue I I ! .--:-----
] Source Testing for limit determination . I I
lPerformance tesl l4[qtions, adjusted process parameters ; ] . I I
. Live Flare work rosulled in excess H2S emissions. Completed mrk IPlugged sample line ledlo inlel tlffi from exhaust tine, cteared plugged line 1 t
1 FCCU put on circulation tg make repairs, unit brought back up to steady stiti after repairs
lHighambienttemperaturecausedlowerflowrale,workedtolowerte.,p"11i*!
lunknom cause. ] IHight-tistoaare,unkomsource.searchforsourceconducted ; L I I ]
HighH2stoflare,unkomsource.Searchforsourceconducted i t I 1
,Daily ca,libration ch6ck exceedance. Recalibrated instrument. .
]FCCU 02 analyzer data invalid. Recalibrateq instrument. Calculated data invalidaled Jue to dependerce on 02 measuiiment
lDaily Drift not performed due to power outage. ]Data recorder failure. Performed maintenance on anallzer.
]Power faiture. ]
rLossot€ampleflow. Flowwasrestored I ;lAnalyzerProbefailure ] I I I
lBroken p?rt on calibration gas system. part reptaced I I I
.Analyzer end of life, Replaced anallaer.
,Anallzer locked up, rebottrl Anityzer ]
fr-earrnmmrtorsarlplqgastine,_- .l i ; 11 i t l
]Sample System coniaminateo. System cteaned out I '
,AnalyzerSofiwareMalfunction,R;;i;"ft*;r;--- I I I I
]lnslrument Air down, not able to actuate solenoids and valves I
, lssues with sample conditioning I I I
1QD failed. Unscheduled maintenance perfomod. lnstrument recalibrated.lLossotsampleflow. Flowwasrestored i I
iBuilding climate control failure led to lmking up of analper. Replaced climate control i
RATA contractor stlrf gtt sample to analfzer, discovered next morning and op€ned :
iAnnualPreventativCMaintenance 1 I I ' ' l
lM;"i;r";i;;;;it'- '- - -- I
1q,;pi";;;6i"i".untlllil'Extreme iold weaiher caused Refinery Wide upsets I l
Software upgrade to tie new monitors into OAS ]
lu dndtyzer, utscovereq next morntng ano oEEnmloAcatibrationsperformed L i i I i
IFCCU02analyzerdatainvalid.CalculateddatalnvatiOateaduetoalpenoeriieonO)miisurement ] I I
lcrinder Gas Audit I I IlMonitormainteninca'-llll]l
,Y'v,nrv,,sP.owE,ile,,. L IJgamoteirstemlentaqement I ] Il:*r":r#,xi4.';:*ff,[r*8"^H'"i]lrli]
Sample System Maintenancetill
lRegen slide valve issues casued ulrit tolwing _ I lrPrmess variations caused emission 6xcess. Made adjustments to unit to bring back in line
i Unit interlock caused high flow to the Jlare, worked to bring unit back online
LPrmess lnterlock of the FCCU, Attempted restart of unit I
lHeatgr lnterlock. BoW[ Fleater baci ontrne. ] I i
lCompressor lnterlock, Compressor biought UacX onti;e I I
lLosl charger to unit. Brought unit back ontin; I I I
I1iqi l12! in tuet gqs retelving to nare, ittempieo to iocale poini ana cbse reriel vatve I.Unit 17 Thermal reactor shutdor,vn, worked on bringing unit 17 bac(online
lPlugging, worked to clean out line
lPump trip caused process swings, worked to bring pump back online
lCompressor ovemhelmed causing unit uplet i
]ARN issues led to fllre seat drums tiberating H2S i
lFacility power black-out i
2 ol2