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ExxonMobil Refinery (2638), Baton Rouge

Releases of Hydrogen Sulfide

LDEQ Accident Number
Accident Date
Point Source(s) Notes Amount of Release
05-BB009-1907

2005-12-09
FLARE
Cause: repairs were being done on an exchanger which caused the events to occur

Followup: No

Notes: the MEA from the scrubber was temporarily diverted to the slop system where it would not cause additional upsets. The tail gas from the tail gas clean up unit was diverted to the incinerators to reduce hydrogen sulfide emissions; the procedures for removing the absorber tower from service will be updated to reflect the potential to have hydrocarbon condense in the MEA system; . Air monitoring completed outside facility.
301.0 pounds
05-BB009-1911

2005-12-09
No information given
Cause: No information given

Followup: No

Notes: Below Reportable Quantities
05-BB009-1903

2005-12-02
tanks, process fugitives, coker venting, docks, wastewater fugitives
Cause: see notes

Followup: Yes

Notes: No Information Given
522.0 pounds
No LDEQ Reported

2005-12-01
E-568 reboiler
Cause: leak in the E-568 reboiler

Followup: No

Notes: the exchanger was blocked out and the leaking tubes will be plugged; report stated this was not preventable because the exchanger was replaced in 1st quarter of 2003, with the previous bundle in service for 20 years; this bundle has previously leaked once due to suspected mechanical damage during installati
4.0 pounds
05-BB009-1898

2005-11-17
No information given
Cause: No information given

Followup: No

Notes: Below Reportable Quantities
05-BB009-1895

2005-11-14
SRLA battery limit block valve
Cause: a flange leak on the SRLA battery limit block valve containing ammonia acid gas leaked along with a minor pinhole leak.

Followup: No

Notes: The inspection history will be reviewed and more frequent inspections will be performed if appropriate; it was not preventable because the gasket failed, and the gasket was appropriate for the servi
117.0 pounds
05-BB009-1889

2005-11-08
E-552B exchanger
Cause:

Followup: No

Notes: an exchanger crew was called out to return E-552A to service; they plan to evaluate if a metallurgy upgrade is needed on this exchanger; was not preventable because the exchanger was retubed in June of 2003 and historically has a longer run life
871.0 pounds
05-BB009-1859

2005-08-04
FLARE- No. 19
Cause: controls for the REA regenerators were switched to the control backup panel, so part of a controller could be repaired. The REA regenerators had difficulty operating and carried over liquid to the SRLA knockout drums triggering an overabundance of chemical releas

Followup: No

Notes: the refinery reduced rates to reduce the production of CAG.Ammonia acid gas production was stopped to allow the maximum amount of CAG to be processed.
698.0 pounds
No LDEQ Reported

2005-07-25
FLARE- No17 & 19
Cause: the sulfur plant shut down causing refinery upset and causing flaring from No17 and No18.

Followup: No

Notes: significant rate reductions were made to refinery units that send hydrogen sulfide to SRLA to reduce flaring.
1,405.0 pounds
05-BB009-1844

2005-07-13
tank732
Cause: C-830 compressor shut down causing ICN unit to shutdown. F-761 control valve was left on control to allowing the liquid level in the ICN product stabilizer tower to continue to tank732. Excess flammable vapor was released.

Followup: No

Notes: it was discovered that the F-761 control valve had not been closed, so it was closed once discovered and the release stopped; procedures will be reviewed and appropriate corrective actions will be ma
13.0 pounds
05-BB009-1801

2005-06-17
F-101 & F-102
tail gas conversion unit
Cause: the sour water strippers had a larger than normal oil layer.

Followup: No

Notes: the controller diverted the tail gas to the incinerators to reduce personnel exposure and the SWS evaluated levels in the feed spheres to ensure no more hydrocarbon would be sent to the SWS and SRLA; the first page of the report states that the hydrogensulfide level was exceeded from 9AM to 9PM on June 17th, and the sulfur dioxide limit from the F-101 and F-102 incinerators was exceeded- even though the actual report only states the levels of sulfur dioxi
No LDEQ Reported

2005-04-30
FLARE- GLA-3x compressor
Cause: the MEA scrubber on No. 2 Light Ends Unit experienced an operational upset due to a high level in the MEA scrubber to overhead drum; GLA-3x compressor shut down causing the RGCU to become overloaded and a gas leakage which flared

Followup: No

Notes: operations attempted to restart GLA-3x and then reduced rates to the FCCU to eliminate flaring; a new alarm was added that is more visible and will alert the controller of increased level in the interstage drum; other items identified by the ongoing investigation will be evaluated and implemented; flaring occurred from 3:20 PM to 4:40 PM on April 30th; the Wet Gas Scrubber exceeded its regulatory limit of 500 PPM of carbon monoxide from 4-6PM; the carbon monoxide concentration increased to 639 PPM fhe hour from 1-2 on May 1st
16.0 pounds
05-BB009-1745

2005-03-15
No2 and No. 3 light end
Cause: control valve malfunction due to changed stream dispositions

Followup: No

Notes: line will be cleaned to eliminate the plug and the water supply source will be changed to reduce potential for plugging on the water wash lines
526.0 pounds
05-BB009-1737

2005-03-09
FLARE (Nos. 5, 7, 8, 9, 17, 19, 20 and 23)
Incinerators, Sites 68 and 69
Waste Water Treatment Unit
Cause: 30 minute power failure on Bulk Power Station #2. See Notes

Followup: No

Notes: Information for both LDEQ Incident Report numbers included on same report. Electrician doing work in the area injured. Investigation underway and findings will be implemented. May put automatic bypasses around filters in case they plug. Emissionswere minimized because some units shutdown; the vent gas from TGCU was sent through the incinerators emitting sulfur dioxide instead of the more harmful hydrogen sulfide. Power failure caused the following refinery units to shut down: No. 10 PipestilSLA-10), West Coker, 200 and 400 Trains on the Sulfer Plant, the Tail Gas Clean-up Unit, No. 2 Powerformer, Heavy Cat Napatha Units, No.1 and No.2 Sour Water Strippers, and some Depronanizers. The following Chemical Plant Units also shut down: Linea
2,671.0 pounds
05-BB009-1721

2005-02-27
FLARE
Cause: the controller responsible for the operation of the Refinery Gas Compression Unit (RGCU) began experiencing problems

Followup: No

Notes: C-50 was started up to eliminate the flaring and was run on manual. Incident not preventable because normal preventative precautions not used due to concern over clanging noises.
1.0 pounds
05-BB009-1713

2005-01-31
Tail Gas Clean Up Unit
Cause: 100 Unit went off ratio because air control valve failed closed.

Followup: No

Notes: The steam leaving the TGCU exceeded the regulatory maximum 12 hour average of 10 ppm of hydrogen sulfide from 3pm to 11pm. Control Valve positioner was repaired. Air bypass valves are being installed on the 100 Unit turnaround. Release unpreventable because this is the first time it has happened and can only be installed while unit is down.
92695

2006-12-17
FLARE - #17 and #19 Flares
Cause: -compressors had to be shut down for repair - compressor trip.

Followup: No

Notes: This incident was not preventable because the compressor trip that caused the flaring incident was unexpected. If the findings of this investigation indicate that the cause of the trip was preventable, a modified report will be issued. Remedial Measures - an investigation is ongoing and the appropriate follow-up actions will be completed. an assistant operator at the Refinery Gas Compression Unit (RGCU) noticed an unusual noise coming from one of the refinery gas compressors C-50. These was evaluated by compressor specialists and it was determined that the compressor had to be shut down for repair. An advanced notification was made in anticipation of the flaring event since the spare compressor was unavailable due to other mechan
5.0 pounds
91379

2006-10-16
FLARE - #17 and #19 Flares
Cause: the cause of the flaring was high pressure in the refinery gas collection system due to a high volume of vent gas from the other refinery units. The source of the high vent gas rate was unable to be determined.

Followup: No

Notes: This incident was not preventable because the remedial actions were initiated before the flaring incident. These actions should have been sufficient to reduce vent gas rates. Two primary actions were initiated to reduce refinery vent gas rates. First, the compressor at the Hydrocracker was lined with the Refinery Gas Compression Unit Compressors to assist with processing refinery vent gas. Secondly, the crude feed rate to Pipestill #10 was decreased. Remedial Actions -an invgation is ongoing and the appropriate follow-up actions will be completed. The reportable quantity for nitrogen oxide has been exceeded.
1.0 pounds
91265

2006-10-11
No Information Given
Cause: No Information Given -Release

Followup: No Information Provided

Notes: The only information included in the letter is that a release occurred and that hydrogen sulfide was released.
90901

2006-09-26
FLARE - #5, #9, #17, #19, #23, #24 Flares
Cause: a control system power failure at the Refinery Gas Compression Unit caused a reduction in compressor capacity due to poor compressor control. As a result of the reduced capacity, the compressors were unable to process all of the refinery gas and the excess gas was routed to the refinery flare syste

Followup: No Information Provided

Notes: This incident was not preventable because the failure of the compressor control system was a result of a failure in both the primary and alternate power supply systems. The back-up power system should have supplied power to the compressor control systemwhen the primary failed to do so because of an electrical malfunction. Remedial Measures - an investigation is ongoing and the appropriate follow-up actions will be completed. Reportable quantities for nitrogen oxide and sulfur dioxide were exceeded.
2.0 pounds
90226

2006-08-24
E-552A and E-553A Exchangers on the Coker
Cause: the E-552A and E-553 Exchangers on the Coker were discovered leaking into Cooling Tower #44. The leak on the E-553A was stopped 20 mins. Later while the leak on the E-552A continued until August 26th, 2006. The leaks are believed to have been caused by accelerated corrosion

Followup: No

Notes: This incident was not preventable because inspection reports on these exchanger bundles indicate that both failed prematurely. Remedial Measures - The existing tube bundles will be repaired/replaced as necessary. Metallurgy of these exchangers will be upgraded. Reportable quantities for volatile organic compounds, hydrogen sulfide, and benzene were exceeded. Note: in the follow up report, it was found that the reportable quantities for hexane, 1,3 Butadiene, and highly reactive volatile organicpounds were exceeded as well. The previously reported level of volatile organic compounds was 8800 and was later found to be 66388, for hydrogen sulfide it was 901/4578, and for benzene it was 59/43
4,578.0 pounds
90043

2006-08-16
E-205 A/B exchanger bank on the Heavy Cat Naptha Unit
Cause: the E-205 A/B exchanger bank on the Heavy Cat Naptha Unit was leaking to Cooling Tower #27. The leak is believed to be from corrosion on the tube bundle.

Followup: No

Notes: This incident was not preventable because the inspection data for this bank of exchangers did not indicate that a failure was imminent. These bundles were tested in January 2005 and were found to have no leaks. Remedial Measures - the exchanger bundle will be inspected and repaired or replaced as appropriate. The reportable quantities for benzene, toluene, naphthalene, volatile organic compounds, xylene mixed isomers, and o-xylene were exceeded. It is possible that the reportable quantities forylene and p-xylene were also exceeded, but available stream specification data does not allow differentiation between the these two isomers
70.0 pounds
89850

2006-08-04
E-513 A exchanger on the 2 Light Ends Unit
Cause: E-513 A exchanger on the 2 Light Ends unit was leaking hydrocarbon to Cooling Tower #25. The leak is believed to have come from corrosion on the hydrocarbon side of the tube bundle.

Followup: No

Notes: This incident was not preventable because previous inspection reports indicate that this exchanger bundle is less than 6 years old and in serviceable condition. Remedial Measures - this bundle will either be replaced with a new bundle or repaired. A metallurgy upgrade to 410 stainless steel is being evaluated. Replacement and/or upgrade of exchanger bundles in similar is also being considered. LDEQ reportable quantities for butenes, propylene, highly reactive volatile organic compounds, and 1,3adiene were exceeded
25.0 pounds
89635

2006-08-01
E-205 C/D exchanger bank on the Heavy Cat Naptha Unit
Cause: the E-205 C/D exchanger bank on the Heavy Cat Naptha unit was leaking to Cooling Tower #27. The leak is believed to be from corrosion on the tube bundle.

Followup: No

Notes: This incident was not preventable because the inspection data for this bank of exchangers did not indicate that a failure was imminent. These bundles were tested in January 2005 and were found to have no leaks. Remedial Measures - the exchanger bundle will be inspected and repaired or replaced as appropriate. The reportable quantities for xylene, benzene, toluene, naphthalene, and volatile organic compounds were all exceeded
32.0 pounds
87870

2006-05-16
D-104 Hydrocracker
Cause: the clamp on the Hydrocracker D-104 overhead line was leaking. The pressure of the overhead gas was reduced and several attempts were made to reseal the clamp, including trying several different kinds of sealant. The leak would stop for a short durationand then return

Followup: No

Notes: As of 7:30am on 5/22/2006 - the date of this letter - the leak was ongoing. In this letter, Exxon claims states that the reportable quantities for hydrogen sulfide and flammable vapor were exceeded only during the first 24 hours of the incident. This incident was not preventable because the clamp was considered to be a permanent repair (installed in Dec. 2005) until the scheduled unit downtime in 2008. Remedial Measures- a larger engineered clamp will be installed over the existing clamp. "
482.0 pounds
87621

2006-05-04
E-3 exchanger on the Coker
Cause: the leak is believed to have been caused by corrosion and erosion

Followup: No

Notes: There is no information whatsoever as to why the accident was preventable. Remedial Measures- the bundle was replaced with a new bundle. In the letter to LDEQ, Exxon states that the reportable quantities for hydrogen sulfide and benzene were exceeded
183.0 pounds
87051

2006-04-08
FLARE - C-30 and C-40 compressor
Cause: at the time of this report, the cause of the flaring incident was unknown and was under investigati

Followup: No

Notes: The only information provided is that the preventability of the incident had not been determined and was under investigation. Remedial Measures are listed the same way. The reportable quantities for nitrogen oxide were exceeded.
1.0 pounds
86722

2006-03-24
FLARE - as a result of a leak from the ammonia gas line to the No. 100 Sulfur Plant (SRLA-100)
Cause: the pipe leaked due to new corrosion hole that had developed under the edge of a clamp that was installed in November. The existing clamp was tightened which did not stop the leak so it was replaced with a new clamp which also did not stop the leak. Since the newly installed clamp did not stop the leak, the old clamp was then reinstalled with a new gasket which still did not stop the leak. The feed spheres to the Sour Water Strippers became full which required the start up of the Sour Water Strippers to the flare syste

Followup: No

Notes: The incident was not preventable because, The clamp was installed in Nov. 2005 due to a pinhole leak from condensate corrosion. At that time, the line was x-rayed and no areas of concern were discovered outside the area under the clamp. Therefore, the corrosion hole that led to the release could not have been predicted. Remedial actions- a similar line exists to the SRLA-200 unit. This line will be inspected and repaired while the SRLA 200 unit is down. The letter to LDEQ ss that the reportable quantities for ammonia, hydrogen sulfide, sulfur dioxide, nitrogen oxide, and nitrogen dioxide were exceeded. Note: there is a time discrepancy - the report states that the incident started at 2:30pm on 03/24/2006 but was discov
1,090.0 pounds
86579

2006-03-18
East Train Hydrofiner (HHLA-E)
Cause: -Exchanger on the East Train Hydrofiner (HHLA-E) was leaking into a cooling tower. The seating surface and gasket on the floating head were upgraded during the turnaround. Operations personnel installed the exchanger correctly . However, when the exchanger was worked offsite, the contracting company installed the wrong bolts in the floating head of the exchanger. The bolts broke due to wet hydrogen sulfide cracking which caused the exchanger to leak. Note: the accident started at 10:00am on 03/17/06 but was not discovered until 1:50pm on 03/18/2006

Followup: No

Notes: The cause of the accident is listed as preventable in the company's report, but there is no explanation whatsoever as to why it was preventable - that section is blank. In the report it does state that further investigation of the incident is currently being conducted. Remedial measure are listed as - the exchanger bolts replaced with appropriate material for the predetermined run length. Reportable quantities were exceeded for hydrogen sulfide and volatile organic compounds
399.0 pounds
86548

2006-03-16
FLARE - Alkylation Feed Preparation Unit
Cause: The Methyl Tertiary-Butyl Ether Unit was converted to an Alkylation Feed Preparation Unit (AFP). The AFP was beginning its initial start up. As the level in one of the towers increased, steam was added to the reboiler to begin producing overhead product. During this time, the safety valves on the tower began relieving to the flare system, which resulted in the reported flare. During the conversion of the unit the overhead pressure meter was reranged in the field, but was no reranged in the control room. Due to this oversight the operator believed he was at a significantly lower pressure and did not immediately discover that the safety valves on the tower had lifted to the flare system. The calculations automtically completed by the flare system

Followup: No

Notes: The cause of the accident is listed as preventable in the company's report, but there is no explanation whatsoever as to why it was preventable - that section is blank. The only remedial measure listed is that the pressure meter range was corrected in the control room. The letter to LDEQ states that reportable quantities of nitrogen oxide and butenes were exceeded.
1.0 pounds
86453

2006-03-13
E-553B Exchanger at the coker
E-553B Exchanger leak at the coker
Cause: -the E-553B exchanger on the Coker was leaking to Cooling Tower #44. The leak is believed to be from the corrosion on the tube bundle.

Followup: No

Notes: Remedial measures - The leaking tube on the E-553 exchanger will be plugged and the exchanger will be pressure tested before it is returned to service. The accident was not preventable because the exchanger had not leaked previously and the tube bundle was approximately 18 months old. The report letter to LDEQ states that the reportable quantities for benzene, hydrogen sulfide, volatile organic compounds, and 1,3-butadine were exceeded.
2,759.0 pounds
86248

2006-03-06
E-515A exchanger on the No. 2 Light Ends Unit
Cause: The E-515A exchanger on the No.2 Light Ends Unit leaked hydrocarbon to a cooling tower. From the cooling tower the hydrocarbon was released to the atmosphere.

Followup: No

Notes: Remedial measures - The leaking tube on the exchanger will be plugged. In their letter to LDEQ, ExxonMobil states that LDEQ reportable quantities for propylene and butene were exceeded
8.0 pounds
86001

2006-02-22
FLARE
Cause: the 100, 200, 400 Sulfur Trains shut down due to high pressure on the primary burners. The 100 Train started up after 2min., the 200 Train started up after 3min., and the 400 train started up after 10min. During the time the Sulfur Trains were shutdown,the pressure increased on the MEA Regenerators, so clean acid gas was flared for 17min. Equipment failed due to a a failure to operate and maintain that equipment in a manner consistent with good engineering practice.

Followup: No

Notes: This event was not preventable -SEE Follow Up Consent Decree letter dated 04/07/2006 - Had the limit switch for valve 182 not been connected in the manner in which it was to the valve posistioner, then the AG Flaring Incident would not have occurred. The fact that valve 192 lacks valve posistion feedback to the Controller to indicate the actual posisiton of the valve was a signifigant contributing factor in this incident. A second contributing factor was that there as no visual checkitiated by the Controller, on the valve to provide absolute certainty that valve 182 was actually open. This was considered, for purposes of stipulated penealties under the consent decree, equipment failed due to a failure to oper
83.0 pounds
85618

2006-02-04
F-600 furnace at No. 2 Reformer / Powerformer Feed Hydrotreater (RHLA-2) / No. 2 Powerformer
Cause: an instrument malfunction caused the F-600 furnace on the No. 2 Reformer to shut down. The shutdown of F-600 resulted in the Powerformer Feed Hydrotreater (RHLA-2) and the No. 2 Powerformer shutting down. The Powerformer is a major supplier of hydrogen to the refinery, and with the reduction in hydrogen supply, several units were forced to significantly reduce rates or shut down. The Feed Preparation Unit feeds RHLA-2 and with this unit shut down a valve was opened to send this stream from Feed Preparation to tankage. There is a second valve in this line that is normally open, but during this time it was closed. The second valve being closed led to a pressure increase in T-31 and caused the safety valve to release. The towe pressure was returne

Followup: No

Notes: Remeidal Measures - An investigation is ongoing and appropriate follow-up actions will be completed. Exxon states in their report that the accident was preventable. Their explanation is that the safety valve did not restart as it should have, nor did the operator know the second valve was closed. Could this be human error in addition to Instrument failur
1.0 pounds
85342

2006-01-23
No Information Given
Cause: No Information Given

Followup: No Information Provided

Notes: No Information is included regarding any remedial measures taken. The only indication that hydrogen sulfide was released was the brief mention in Exxon's letter of notification that says, After futher evaluation, we have determined that noreportable quantities or limits from our hydrogen sulfide Continuous Release Report have been exceeded.
85263

2006-01-19
No. 2 Powerformer Unit T-4X
Cause: a leak on the shell of their tower (T-4X) is believed to have been caused from the failure of the mortar in the joints of the tile which lines the inside of the tower, which allowed acid to attack the carbon steel shel

Followup: No

Notes: Incidents 06-00380, 06-00401 occurred simultaneously on January 19th and on Jan. 20th 06-00406 occurred, overlapping with the first two. The reportable quantities for highly reactive volatile organic compounds and flammable vapors were exceeded when the emissions from these three events were summed over the first 24 hour period beginning with the initiation of the release from the No. 2 Powerformer Unit. With regard to the 24 hour period beginning with the release at the MTBE Unit, there wereeportable quantity exceedances for this period of time. The emissions limit exceeded the reportable quantity threshold only during the time when all three incidents were taking place simultaneously. The mortar in T-4X will be replaced with a Furan r
85270

2006-01-19
#2 Light Ends Unit (E-568)
Cause: #2 Light Ends Unit experinenced a leak from their rebolier exchanger. The failure mechanism causing the leak in the exchanger is listed as unknown.

Followup: No

Notes: Incidents 06-00380, 06-00401 occurred simultaneously on January 19th and on Jan. 20th 06-00406 occurred, overlapping with the first two. The reportable quanitites for highly reactive volitile organic compounds and flamable vapors were exceeded whenthe emissions from these three events were summed over the first 24 hour period beginning with the initiantion of the rlease from the No. 2 Powerformer Unit. With regard to the 24 hour period beginning with the release at the MTBE Unit, there were nportable quanity exceedances for this period of time. The emissions limit exceeded the reportable quanitity threshold only during the time when all three incidents were taking place simultaneously. The mortar in T-4X will be replaced with a Furan re
2.0 pounds
101896

2007-12-26
FLARE-Flare #19
FLARE-Flare 19
Cause: Motor operated valve found in open position and upstream control valve was leaking acid gas to flare

Followup: Yes

Notes: Report states that incident is still under investigation and follow up report will be completed once investigation is complete.
100830

2007-11-06
air release
Cause: no information given

Followup: No

Notes: no information given
99374

2007-09-12
FLARE-Flare #5,8,9,17,23
Release
Cause: c-101 Recycle Compressor on the HCLA unit shutdown due to an instrumentation tubing failure. Compressor trip activated the units emergency depressureization procedure.

Followup: Yes

Notes: The unit was depressurized immediately in accordance to emergency procedures. Tubing on the seal oil pump was replaced and properly connected. The investigation is ongoin so an appropriate follow up will be completed. Under Investigation.
3,891.0 pounds
98706

2007-08-16
air release
Cause:

Followup: Yes

Notes: Once detected regenerated caustic use at the wet gas scrubber was reduced and fresh caustic use was increased. This action reduced the potential for sulfide entrainment to the settling ponds.
986.0 pounds
97339

2007-06-23
steam line leak
Cause: OTHER-Overpressure of incinerators during deviation of tail gas between TGCU to SRLA

Followup: No

Notes: Sulfur pit and tail gases were directed back to TGCU. Leaking portion of tail gas line was repaired.
460.0 pounds
97336

2007-06-22
Leak-Idle stream line
Cause: Internal acid corrosion

Followup: Yes

Notes: Under Investigation- If investigation shows different causal factor, a follow up will be given. The leaking portion of the line was clamped to stop releas
133.0 pounds
97173

2007-06-17
Leak-tower leak
Cause: Internal and external

Followup: Yes

Notes: Tower shut down to stop leak. Tower repaired before returned to service
81.0 pounds
96849

2007-06-06
flange leak
Cause: OTHER-Overpressure of flange line

Followup: No

Notes: unit was depressurized immediately in accordance with emergency procedures.
1,237.0 pounds
95549

2007-04-22
Flare/Safety valve release
Cause: leaking seal/safety valve release

Followup: Yes

Notes: Several actions were taken to avoid or reduce the environmental impacts from this incident. The different gas streams were redirected in a manner appropriate to minimize emissions.
154.0 pounds
94172

2007-02-23
Exchanger leak
Cause: underdeposit corrosion

Followup: No

Notes: Leaking exchangers were removed from service. The metallurgy of the exchangers is being evaluated for upgrading.
39.0 pounds
94023

2007-02-17
safety valve release
Cause: safety valve release

Followup: No

Notes: unit feedrate was reduced until the faulty indicator could be repaired.
1,640.0 pounds
93177

2007-01-09
system release
Cause: Emergency Depressurization System inadvertently activated

Followup: No

Notes: Emergency Depressurization System was restarted and has been bypassed until source of malfunction can be determined.
1,038.0 pounds
93020

2007-01-03
FLARE-Flare #5,7,17,19
Cause: OTHER-Electrical failure of Coker units

Followup: No

Notes: Personnel initiated startup of idle compressor recovering most of coker gas. Alternate electrical coordination settings and power supply designs are being evaluated for this system.
23.0 pounds
111659

2008-12-29
NIG
Cause: An exchanger leaked and material got into cooling tower water.

Followup: No

Notes: The exchanger was isolated to stop the leak. Release was BRQ.
110987

2008-11-24
NIG
Cause: Emissions through a cooling tower, but no information provided regarding the cause.

Followup: No

Notes: LDEQ report indicates the release could exceed RQ for H2S and benzene, but refinery report indicates no RQs were exceeded.
109926

2008-10-08
NIG
Cause: According to the LDEQ incident report, a leaking heat exchanger released H2S through the cooling water tower.

Followup: No

Notes: Exxon was trying to shut down the exchanger to stop the leak. This release is BRQ.
109134

2008-09-15
feed piping to sulfur recovery unit
Cause: According to the LDEQ incident report, a small leak under the insulation on feed piping to sulfur recovery unit leaked ammonia and H2S.

Followup: No

Notes: Insulation stripped to stop the leak. Release was BRQ.
108842

2008-09-09
NIG
Cause: According to the verbal report, Exxon lost their primary control device on the Sulfur Recovery Unit so they diverted to the secondary control device. They reduced rates to minimize flaring amounts.

Followup: Yes

Notes: LABB only has access to the SPOC verbal reports. These initial reports estimate that both sulfur dioxide and hydrogen sulfide were released above reportable quantity. Material went offsite. LABB only has access to the SPOC verbal report.
100.0 pounds
108690

2008-09-05
Flare
Cause: STORMS-startup brought on flaring after rapid shutdwon due to Hurricane Gustav

Followup: Yes

Notes: refinery is undergoing startup operations. All efforts are being made to minimize environmental impacts. A follow up report will be submitted when startup flaring has ended.
3,806.0 pounds
108484

2008-09-02
FLARE-Sour Water Stripper routed to flare
Cause: STORMS-Hurricane Gustav

Followup: No

Notes: no information given
5,496.0 pounds
108376

2008-08-26
Leak-valve was leaking tail gas
Cause: Process upset-air operated valve leaking tail gas back into valve

Followup: No

Notes: The air operated valve was hand tightened to ensure closure, the valve lineup was restored to norma
101.0 pounds
107580

2008-07-29
Exchanger
Cause:

Followup: No

Notes: Due to the presence of a film on the surface of the water in the cooling tower basin, it was suspected that an exchanger was leaking oil into the cooling water. After diligent searching over the last week, no leaking exchanger has been identified. Since the initial sighting, the film has disappeared. Exxon will continue to closely monitor the water quality in the cooling tower through regular sampling and unit observations. No reportable quantities have been exceeded.
107539

2008-07-26
Hydrocracker unit reactor #101 safety valve flange
Cause: Hydrocracker unit Reactor #101 safety valve flange is leaking.

Followup: No

Notes: source is subject to facility's Leak Detection and Repair program and is permittable activity under Hydroprocessing Complex Title V permit.
107513

2008-07-25
flow meter
Cause: Water leaked out of a flow meter.

Followup: No

Notes: The leak contained hydrogen sulfide and sour water.
106981

2008-07-07
flare
Cause: Cause of release to the air form the flare is unknown.

Followup: No

Notes: Written report states no reportable quantities were exceeded.
100.0 pounds
106451

2008-06-14

Cause: Small drip in piping is leaking Naptha to concrete within the facility.

Followup: No

Notes: A pad was placed underneath the piping until the problem can be corrected.
100.0 pounds
106262

2008-06-07

Atmospheric release/FLARE-Flare 17,19,23
Cause: The C-101 Recycle Compressor on the HCLA unit shut down due to a fault in the transformer that supplies power to the compressor motor. The compressor trip automatically activated the units emergency depressurization procedures, which caused gases in the HCLA reactor system to be vented to the atmosphere via the condensable blow down drum. The transformer failed due to overheating. The air conditioner in the substation was found to have failed causing the temperature in the building to increase and the transformer to overheat. FLaring also occurred.

Followup: Yes

Notes: The unit was depressurized automatically in accordance with the emergency procedures. Temporary ventilation conditioning was installed in the substation to cool the remaining electrical equipment. Total amount of flammable vapor released was 108,206 pounds. Total amount of VOC's released was 93,904 pounds
3,415.0 pounds
106154

2008-06-03
flare
Cause: Chemicals are flaring.

Followup: No

Notes: They are in the process of trying to resolve which process unit the chemicals are coming from.
106069

2008-06-01
leaking pipe
Cause: Acid gas leaking from a pipe.

Followup: No

Notes: The line will need to be blocked at some point. Had to locate the source of the leak first.
106061

2008-05-30

Cause: Some safety valves may be leaking into a flare.

Followup: No

Notes: The safety valves were isolated in an effort to secure the incident.
100.0 pounds
105934

2008-05-26
Unit SRLA Tyler 310
Cause: Flange leak occurred on unit SRLA Tyler 310.

Followup: No

Notes: A crew tightened the flange and repaired as needed.
105920

2008-05-24

Cause: A pin hole leak develeped on a thermal well.

Followup: No

Notes: The plan is to clamp the line or put a leak box around it.
105761

2008-05-19

Cause: They were putting new instrumentation on a mixed gas oil tank, starting it up after maintenance.

Followup: No

Notes: Release of unknown amounts of extremely noxious smelling gas. They are done with the start up.
105542-105544

2008-05-11
safety valve release/ FLARE-Flare 17,23
Cause: process upset/under investigation

Followup: Yes

Notes: In response to the suspected exchanger tube leak, the unit was shut down per appropriate procedures. Safety valve inlet line was cleaned and replaced.
2,000.0 pounds
105191

2008-04-29
overhead piping in LELA Unit
Cause: A pinhole leak occurred on the overhead piping in the LELA Unit.

Followup: No

Notes: Release is estimated at 3.2 pounds per hour. Personnel were currently working to see how to isolate the line at time of SPOC report.
104962-104935

2008-04-20
leak/FLARE-Flare 5,9,19,20,24
Cause: Equipment failure-Hydrocracker unit down; Pressure Swing Absorber out of service

Followup: No

Notes: Safety valve released itself once the pressure stabilized. Lights end section was depressured to stop H2S leak, which caused many flares to burn. Light ends depressured. Stream was lined up to the tower to stop flarin
4.0 pounds
102960/102918

2008-02-08
FLARE-Flare 5,17,19
Cause: Process Upset-recycle gas compressor shut down due to process upset./Other-high pressure in the refinery gas collection system due too a high volume of vent gas from other refinery units.

Followup: No

Notes: Process upset conditions at the catalytic cracking unit were resolved and recycle gas compressor was restarted to stop flaring. When the high pressure burner line overpressured, efforts were made to reduce the amount of gas sent to HPBL and increase gas amount taken by Enterg
1.0 pounds
102686

2008-01-29
FLARE-Flare 9
Cause: equipment failure

Followup: No

Notes: Written report from Exxon Mobile surrounding the flaring accident stating that the source was found to be several leaking evacuator valves on the flare gas compressor system. Steam was injected into the flare drum, and RGCU gas gointo to the flare drumwas blocked out. The leaking evacuator valves were also replace
1.0 pounds
102529

2008-01-23
FLARE-Flare 9
Cause: Equipment Failure( leaking RGCU evacuator valve)

Followup: No

Notes: Report from Exxon Mobile surrounding the flaring incident stated that steam was injected into the flare drum, and the RGCU gas going to the flare drum was blocked out. The #9 flare was isolated from the rest of the flaring system. Report stated the leaking evacuator valve would be replace
1.0 pounds
102274

2008-01-15
no informaiton given/leak
no information given/leak
Cause: no information given

Followup: No

Notes: Written notification from Exxon Mobile surrounding the leak that occurred at the facility stating that no reportable quantities had been exceeded.
2.0 pounds
119856

2009-12-04
T2-61A
Cause: Pump seal leak on T2-61A.

Followup: No

Notes: LDEQ report states "propylene, ethylene, H2S and benzene expected to exceed reportable quantities. ExxonMobil in its report states that reportable quantities were not exceeded. Isolated the leak.
117732

2009-09-04
No Information Given
Cause: A pinhole leak was found and repaired.

Followup: No

Notes: Release is BRQ.
576.0 pounds
117459

2009-08-22
no information given
Cause: Compressor malfunctioned leading to flares.

Followup: No

Notes: RQ not exceeded. Company reports and State Police HAZMAT report differs in pollutants.
117013

2009-08-04
No Information Given
Cause: A leak occurred in a cooling tower where the discharge goes to water treatment system on site.

Followup: No

Notes: Release is BRQ. Incident may be caused by different water cooling tower which is still under investigation.
116863

2009-07-28
flare system
Cause: PCLA-2 Fluid Catalytic Cracking Unit restart caused discharge. Unit unexpectedly shutdown earlier in the day. Restart caused pressure to build and ultimately flaring.

Followup: No

Notes: RQ for SO2 exceeded. State Police HAZMAT report and company reports differ in pollutants. Feed was reduced o the unit, temperatures within unit was decreased and compressor was restarted.
116539

2009-07-17
7 flares
7 unspecified flares
Cause: Compressor lost which caused flaring for 7 of the flares.

Followup: No

Notes: RQ not exceeded.
116294

2009-07-07
flare system
Cause: Safety valve lifted in the plant which caused 6 different flares to ignite.

Followup: No

Notes: This release estimate exceeds RQs. The incident was secured. LABB only has access to the SPOC verbal report, and all of these quantities are the initial estimates.
100.0 pounds
115170

2009-05-21
No Information Given
Cause: According to the SPOC verbal report, a release occurred at ground level due to equipment cleaning.

Followup: No

Notes: This release is BRQ.
115082

2009-05-19
pressure relief valve
pressure relief valves
Cause: An Unexpected shutdown of a hydrocracker was caused by a failed thermocouple. The thermocouple failed, resulting in a low temperature reading, but then began reading erroneously high. The false high temperature reading resulted in the automatic emergency shutdown of the hydrocracking unit. The thermocouple is connected to the emergency shutdown to protect the unit from temperature runaway. The shutdown device reacted as designed.

Followup: No

Notes: Unit was shutdown and area secured. The RQs for flammable vapor, VOCs, H2S, and benzene was exceeded.
3,415.0 pounds
114924

2009-05-12
flare system
Cause: Personnel was making valve alignment changes when a block valve on the suction of the coker compressor was inadvertently closed. This caused the pressure to build in the overhead system until the pressure exceeded that of pressure vent set point. The pressure vents opened, resulting in overhead vapor to be released to the flare system, which resulted in the flaring of the hydrocarbon.

Followup: No

Notes: The RQ for SO2 was exceeded. The valve was reopened. Additional training and discussion was held for the personnel about the importance of valve misalignment. Company letter and State Police HAZMAT report differs on pollutant released.
100.0 pounds
114636

2009-05-01
No Information Given
Cause: Leak occurred on pipe going to analyzer.

Followup: No

Notes: This release is BRQ.
114479

2009-04-27
FLARE
Cause: Flaring occurred when compressor tripped off line.

Followup: No

Notes: RQ not exceeded. Restarted compressor. No LDEQ report or follow up.
114483

2009-04-26
safety valve on coker drum
safety vavle on coker drum
Cause: Safety valve release on coker drum.

Followup: No

Notes: RQ not exceeded. Material rerouted to another drum.
113842

2009-03-31
make-up hydrogen compressor (C-102B)
Cause: Make-up hydrogen compressor (C-102B) malfunctioned which caused a higher rate of hydrogen into C-102 compressor. This increased pressure which resulted in a safety valve release and caused flaring.

Followup: No

Notes: Release exceeded SO2 RQ. The safety valve was removed from service. Pressure maintained by companion safety valve. Compressor will be repaired. Company report and State Police HAZMAT report differs on pollutants released.
2.6 pounds
112755

2009-02-16
NIG
Cause: According to the SPOC verbal report, a leak to a cooling tower occurred, but no information provided about the cause. The source of the leak is still under investigation.

Followup: No

Notes: RQ not exceeded.
127376

2010-10-28
FLARE
Cause: Pressure instrument failed & resulted in flaring. FLARE.

Followup: No

Notes: BRQ. Below Reportable Quantities.
128655

2010-10-10
Furnaces, Incinerators, and Crude Tanks
Cause: A follow up report was submitted March 12, 2013. This report has the same accident number, and is filed under 1286550 in this database to separate the two incidents in their appropriate years. This report serves as written notification to comply with 40 CFR 302.8, which requires the owner or operator of facility to submit written follow up information for the verbal reporting of a continuous release(CRR). On October 10, 2010 Exxon Mobil Corporation's Baton Rouge Refinery made an initial notification to the NRC, the LA State Police Hazardous Materials Unit, the East Baton Rouge Parish Fire Department, and the LDEQ of the Refinery's continuous releases of hydrogen sulfide. Per continuous release reporting requirements, a one-time follow up report will be filed within thirty days of the anniversary of the source change. Thereafter, annual reassessments will be issued if there is a Statically Significant Increase or a change in the source of release. Report states that hydrogen sulfide is being released continuously due to "burning natural gas as furnace and incinerator fuel".

Followup: Yes

Notes: Within a mile radius of this facility live more than 1000 persons, 13 schools, the Mississippi River, and Monte Sano Bayou. The release is a result of burning natural gas as furnace and incinerator fuel and it is released continuously without interruption.
6,792.0 pounds
126685

2010-09-26
Hydrocracker unit
Cause: Hydrogen sulfide leak in hydrocracker unit set off alarm.

Followup: No

Notes: Shut down pump and depressurized--no further details given. This release was BRQ.
124467

2010-06-25
cooling water tower
Cause: There was a leak through cooling water tower., but the cause is unknown at this time.

Followup: No

Notes: LDEQ states that an initial report indicated there maybe an exceedance of RQ for H2S, but a follow up report indicated that sampling revealed the release was BRQ. LABB only has access to the LDEQ incident report.
124370

2010-06-22
heat exchanger bundle in hydrocracker unit [HCU]
Cause: Leak in heat exchanger [tubing] bundle in the hydrocracker unit. H2S monitor went off.

Followup: No

Notes: A new bundle has been ordered and present one will continue to operate as the RQ not exceeded. LABB only has access to the LDEQ report.
21.0 pounds
124195

2010-06-16
compressor - hydrocracker unit [HCU]
compressor hydrocracker unit [HCU]
Cause: Leak in compressor in the hydrocracker unit.

Followup: No

Notes: Compressor was shut down. LDEQ report states that no reportable quantities were exceeded. LABB only has access to the LDEQ report.
124190

2010-06-12
Tank 261
Cause: Leaking access hatch on tank #261 released mixed gas oil.

Followup: No

Notes: Repaired hatch by tightening bolts to stop leaking.
122774

2010-04-14
FLARE: PCLA-2 [CCU]
Cause: Facility was called after smoky flare was noticed. A level instrument critical to unit operations that malfunctioned caused flaring. Exceeded RQ for SO2. Follow-up letter states that a recent analysis of the refinery flare system resulted in updated release amount: 1653 lbs

Followup: No

Notes: The unit was shut down to end the release. This incident is under investigation to determine the root cause in order to prevent reoccurrence. This release exceeded the 1,000 pound RQ value for SO2. LDEQ incident report indicate that this incident is #122774 and State police #10-01932. However, the refinery letter indicates that this incident is incident #s 122774, 123224, and 124285 and state police numbers 10-01932, 10-02386, 10-03389.
120862

2010-01-19
sulfur recovery unit
Cause: Sulfur Recovery Unit process upset. No further details provided.

Followup: No

Notes: Release is BRQ.
120697

2010-01-10
Coker unit
Cause: Coker unit had pressure release valve blow briefly into blowout drum.

Followup: No

Notes: Release was secured and BRQ.
120611

2010-01-08
flare
Cause: Over pressure to flare due to cold weather. LDEQ indicates it is a safety issue and flared with smoke. No information given as to amounts of releases.

Followup: No

Notes: LABB only has access to LDEQ incident report. No information provided if release was BRQ.
135838

2011-12-10
Furnace from a burner line
Cause: At the time of initial notification, Exxon personnel was attempting to find the source of the problem. No information given about the cause in the written report after the release was all clear.

Followup: No

Notes: No remedial actions mentioned. Initial reports indicated a release of over 500 lbs of sulfur dioxide, but Exxon determined that no RQs were exceeded in the written report. The RQ for sulfur dioxide is 500 pounds.
134100

2011-09-20
#8 depropanizer
Cause: Alarm went off on console because it lost pressure. They discovered a pump lost a seal on the number 8 depropanizer overhead.

Followup: No

Notes: Approximately 35 pounds of material was release, the majority of which was propane. Less than one pound of hydrogen sulfide was released. To end the release, the pump was shut down, isolated, and depressurized. An initial report indicated a release of greater than 1000 pounds of flammable gas and more than 100 pounds of hydrogen sulfide. However, upon further review from ExxonMobil, Exxon confirmed that no RQs were exceeded.
1.0 pounds
131965

2011-06-23
Pin hole leak in piping
Cause: A pin hole leak was found in a piece of piping connected as discharge from the Hydro Cracker Effluent.

Followup: No

Notes: No information given regarding remedial action. CO monitor was used to detect the hydrogen leak and read 600ppm. BRQ
130592

2011-04-13
Cooling Tower Water System
Cause: There was an exchanged leak into a cooling tower water system resulting in a release.

Followup: No

Notes: This release was BRQ. The leak was stopped. 346 pounds of material were released. More than 100 pounds of hydrogen sulfide and more than 10 pounds of 1,3-butadiene may have been released as a result of this incident.
100.0 pounds
130418

2011-04-05
Primary Burner in the Sulfur Unit
Cause: A pinhole leak in the sulfur unit caused an ammonia and hydrogen sulfide leak.

Followup: No

Notes: This release is BRQ. The unit was isolated and repaired.
2.0 pounds
130351

2011-04-05
Primary burner in the 200 Unit of the Sulfur Unit
Cause: Pin hole leak from the primary burner in the 200 Unit of the sulfur unit.

Followup: No

Notes: Isolated leak and repaired.
2.0 pounds
130393

2011-04-03
cooling tower: exchanger
Cause: This incident report documents two incidents: one that occurred on April 4 and one that occurred on April 5. An exchanger leaked H2S in cooling water tower. No reportable quantities are being released as ExxonRefinery is executing shutdown procedures for furnace F-901.

Followup: No

Notes: There are a few inconsistencies in the Refinery report and the LDEQ incident report. The LDEQ incident report states that accident occurred on April 3. It also says the state police number is 11-01875. However, both reports refer to incident # 130393.
130240

2011-03-29
Flare: Unspecified flare
Cause: The GLA-3X gas compressor shut down resulting in flaring.

Followup: No

Notes: The 2x compressor was started to stop flaring.
130000

2011-03-18
Cooling Tower #25: exchanger
Cause: LDEQ states that a leak developed in the exchanger at cooling tower #25, resulting in the release of volatile organic compounds, hydrogen sulfide, benzene and propylene.

Followup: No

Notes: The cooling tower exchangers were blocked out and repaired. LDEQ report only. No Refinery Letter.
2.0 pounds
129080

2011-02-07
Unspecified line
Cause: There is no information regarding the cause, but oil was observed below the line and a small vapor was seen coming from the line.

Followup: No

Notes: The majority of what was released was water. The line was repaired. The incident date on the SPOC report and LDEQ (2/7/11) do not coincide with the incident date on the Incident Report (2/6/11) submitted by the refinery. Wrong Date Reported.
128902

2011-01-28
FLARE: #4 Unit
Cause: As the #4 unit was starting up, it had a unit swing. To relieve the pressure, flaring took place. During the same 24 hours, the Powdered Catalyst Unit (PCLA) also underwent startup operations. Difficulties with compressor GLA-2X during startup resulted in additional flaring. As a result of this flaring, 1616 pounds of sulfur dioxide was released. Combined, these two sources release 1,716 pounds of sulfur dioxide. However, in a follow-up letter dated March 21, 2011, ExxonMobil stated that 2,063 lbs of sulfur dioxide were released.

Followup: Yes

Notes: This release is RQ. To end the Light Ends Flaring, pressures on the 4 West Rerun and 4 West Splitter towers were reduced. To end the PCLA flaring, compressor GLA-2X was started. To prevent recurrence, procedures will be reviewed for the Light Ends area startups following unplanned downtimes. Additionally, startup procedures for the GLA-2X compressor will be reviewed.
0.3 pounds
128794

2011-01-20
Tank 261: Pressure Valve Vent
Cause: Sulfur dioxide, flammable gas, and hydrogen sulfide at levels below reportable quantities were released due to a leak in the pressure valve vent on Tank 261.

Followup: No

Notes: BRQ. Vapor recovery was performed. Refinery letter states that no reportable quantities were exceeded and this is considered a courtesy notification."
128526

2011-01-07
Flange
Cause: A flange leak occurred in the sulfur unit. Sulfur dioxide and hydrogen sulfide were released.

Followup: No

Notes: BRQ. After further evaluation, ExxonMobil determined that no reportable quantities were exceeded. Mechanical unit cranked down on the bolts to secure the leak.
2.3 pounds
128445

2011-01-01
Reboiler
Cause: LDEQ states that the facility staff believe that a leak developed in a reboiler on a depropanizer, causing a hydrogen sulfide leak of more than 100 pounds of hydrogen sulfide. In refinery letter, Exxon states that only 29 pounds of material were released which is BRQ.

Followup: No

Notes: BRQ. The leak was secured.
29.0 pounds
145216

2012-12-07
Flare Gas Recovery System
Cause: A safety valve at the LELA-S unit lifted, but was later determined that all emissions were captured by the refinery flare gas recovery system. ExxonMobil states that were no emissions to the environment as a result of this event.

Followup: No

Notes: ExxonMobil's notification states that there were no emissions to the environment as a result of this event. Correspondence reports from LDEQ and ExxonMobil display that hydrogen sulfide and flammable vapor were released from a unit, but later ExxonMobil stated that all gases were contained by the flare gas recovery system and that nothing was released into the environment.
144281

2012-10-29
MOV XD 21 valve
Cause: The Coker D-1D drum overhead valve, MOV XD 21, leaked.

Followup: No

Notes:
1.5 pounds
135182

2012-10-24
HCLA unity C-102B compressor
valve at the HCLA unity C-102B compressor
Cause: HCLA unit C-102B compressor developed a leak near the threads of the valve. Approximately 52 pounds of volatile organic compounds (VOCs), 221 pounds of flammable vapor, and less than 1 pound of hydrogen sulfide (H2S) were released.

Followup: No

Notes: After further evaluation, ExxonMobil determined that no reportable quantities were exceeded.
143294

2012-09-17
control valve R002
Cause: A flame was discovered at the top of HCLA D-115 condensable blowdown drum stack. 803 pounds of flammable vapor and 60 pounds of Hydrogen Sulfide were released.

Followup: No

Notes: Steam was injected into the stack to extinguish the flame. Control valve R002 was discovered leaking. No reportable quantities were exceeded.
60.0 pounds
143543

2012-08-29
2795-V6, Refinery Tank Farm
Cause: ExxonMobil Refinery Plant reported several operating compliance matters and potential RQ exceedances resulting from upset conditions caused by Hurricane Isaac. Tank 109: An external roof vent was discovered missing on tank 109. There was no damage to the floating roof of this tank and there are no additional emissions from the missing vent on the external roof of tank 109. Tank Socks: Multiple tank socks were discovered missing. Tank 785 Pontoon Covers: Four pontoon covers were discovered blown off tank 785. External Storage: No flaring occurred as a result of the temporary shutdown/curtail of butane and isobutane to alternative despositions to eliminate potential flaring Continuous Emissions Monitoring System (CEMS): CEMS analyzers at the BRRF may have experienced less than 90% data availability.

Followup: No

Notes: Tank 109: There were no additional emissions from the missing vent on the external roof of tank 109. Tank Socks: The missing socks will be replaced as soon as possible (or within 45 days). Tank 785 Pontoon Covers: Upon discovery, the pontoon covers were repositioned. There were no excess emissions. External Storage: No flaring occurred as a result of the temporary shutdown/curtail of butane and isobutane to alternative despositions to eliminate potential flaring Continuous Emissions Monitoring System (CEMS): ExxonMobil is working to determine the extent to which the CEMS analyzers may have malfunctioned. The findings will be included in the CEMS quarterly report. The report lists a summary of estimated pounds released until repairs. The report suggests that estimates are assuming it would take 45 days to make necessary repairs.
1286550

2012-03-12
Crude Tanks
Furnaces, Incinerators
Cause: This is an update on a continuous release notification submitted by ExxonMobil on 1/18/2011. The 2011 report has the same incident number, and is filed in this database under 128655 (SERNO # 4813), without a following zero, to keep the two reports in their respective years. This report serves as written notification to comply with 40 CFR 302.8, which requires the owner or operator of facility to submit written follow up information for the verbal reporting of a continuous release(CRR). On October 10, 2010 Exxon Mobil Corporation's Baton Rouge Refinery made an initial notification to the NRC, the LA State Police Hazardous Materials Unit, the East Baton Rouge Parish Fire Department, and the LDEQ of the Refinery's continuous releases of hydrogen sulfide. Per continuous release reporting requirements, a one-time follow up report will be filed within thirty days of the anniversary of the source change. Thereafter, annual reassessments will be issued if there is a Statically Significant Increase or a change in the source of release.

Followup: No

Notes: On March 12, 2013, a first anniversary follow-up letter to initial notifications made in February 2012 of a change in sources of the continuous releases of hydrogen sulfide with updates on these sources and amount release. In addition to continuous release from furnaces and incinerators, ExxonMobil identified the potential for hydrogen sulfide to be present in selected crude and process oil streams. Exxon Mobil has submitted a permit renewal to the LDEQ to incorporate hydrogen sulfide emissions in crude tanks. For 2012-2013, estimates for the rate of release of hydrogen sulfide ranged from 5 lb/day to 14 lb/day from furnaces and incinerators. This corresponds to annual emissions of 1825 lbs for the lower bound and 5110 lbs for the upper bound. LABB researchers have averaged these two estimates for the release amount here. ExxonMobil's total estimate of hydrogen sulfide releases from crude tanks was 54 lb for the year, which is slightly below the lower bound rate of 0.15 lb/day. The lower bound for daily emissions is .15 lbs/day and the upper bound is .58 lb/s day. This corresponds to annual emissions of 54.75 lbs for the lower bound and 211.7 lbs for the upper bound. LABB researchers have averaged these two estimates for the release amount included here.
3,467.5 pounds
1286550

2012-03-12
Crude Tanks
Furnaces, Incinerators
Cause: This is an update on a continuous release notification submitted by ExxonMobil on 1/18/2011. The 2011 report has the same incident number, and is filed in this database under 128655 (SERNO # 4813), without a following zero, to keep the two reports in their respective years. This report serves as written notification to comply with 40 CFR 302.8, which requires the owner or operator of facility to submit written follow up information for the verbal reporting of a continuous release(CRR). On October 10, 2010 Exxon Mobil Corporation's Baton Rouge Refinery made an initial notification to the NRC, the LA State Police Hazardous Materials Unit, the East Baton Rouge Parish Fire Department, and the LDEQ of the Refinery's continuous releases of hydrogen sulfide. Per continuous release reporting requirements, a one-time follow up report will be filed within thirty days of the anniversary of the source change. Thereafter, annual reassessments will be issued if there is a Statically Significant Increase or a change in the source of release.

Followup: No

Notes: On March 12, 2013, a first anniversary follow-up letter to initial notifications made in February 2012 of a change in sources of the continuous releases of hydrogen sulfide with updates on these sources and amount release. In addition to continuous release from furnaces and incinerators, ExxonMobil identified the potential for hydrogen sulfide to be present in selected crude and process oil streams. Exxon Mobil has submitted a permit renewal to the LDEQ to incorporate hydrogen sulfide emissions in crude tanks. For 2012-2013, estimates for the rate of release of hydrogen sulfide ranged from 5 lb/day to 14 lb/day from furnaces and incinerators. This corresponds to annual emissions of 1825 lbs for the lower bound and 5110 lbs for the upper bound. LABB researchers have averaged these two estimates for the release amount here. ExxonMobil's total estimate of hydrogen sulfide releases from crude tanks was 54 lb for the year, which is slightly below the lower bound rate of 0.15 lb/day. The lower bound for daily emissions is .15 lbs/day and the upper bound is .58 lb/s day. This corresponds to annual emissions of 54.75 lbs for the lower bound and 211.7 lbs for the upper bound. LABB researchers have averaged these two estimates for the release amount included here.
133.2 pounds
142210

2012-02-24
No Information Given
Cause: Less than 1 lb of H2S was released as a result of this event.

Followup: No

Notes: The report was made later than 7 days after the incident and verbal notification occurred.
1.0 pounds
137359

2012-02-18
FLARE: Flare #7
Cause: Excessive rainfall caused an electrical ground fault to occur with some of the compressor's control instrumentation causing the three compressors to shut down. excesses gases were released to the flares.

Followup: No

Notes: Air monitoring occurred and eventually two of the three compressors were brought back on-line and flaring ceased. There is no refinery Incident report and no SPOC report attached to this file.
147.6 pounds
137212

2012-02-14
West Coker T-101
Cause: The West Coker T-101 safety valve lifted when the gas balance line valves went into the fail close position due to the failure of the Programmable Logic Controller (PLC). A fault signal was received by the PLC card causing it to fail.

Followup: No

Notes: The PLC card was reset.
202.0 pounds
136880

2012-02-01
Flare #17
Cause: The Alkylation Unit lost a cooling tower pump (P-451B), which resulted in the D-301 safety valve lifting and venting to flare #17 for 8 minutes.

Followup: No

Notes: ExxonMobil later determined that no reportable quantities were exceeded.
0.1 pounds
152732

2013-12-05
HCLA Unit
Cause: On December 5, the Recycle Feed pump at the HCLA unit experienced an unplanned shut down, causing material to be released to the site's flare gas system and atmospheric safety valves to lift. The unplanned shutdown occurred while swapping the in-service pump with a spare pump for a preventable maintenance inspection. The Recycle Feed pump was immediately isolated and unit feed rate was safely and quickly decreased to minimize flaring and emissions to the atmosphere. This incident is under investigation to determine the exact root cause and to provide mitigating steps to prevent recurrence. The reportable quantity for flammable vapor, VOC, hydrogen sulfide, sulfur dioxide, and benzene was exceeded as a result of this event. Follow up report submitted 1/30/2014. Investigation of the accident indicated the failure occurred due to a reverse over speed event caused by a failed pump discharge check valve.

Followup: Yes

Notes: Immediately upon the pump shutdown, unit feed rate was safely and quickly decreased to minimize flaring and emissions to the atmosphere. Installed two new check valves on the common discharge line in this service to mitigate backward flow.
811.0 pounds
151767

2013-10-22
Combined cooling tower return line
Cause:

Followup: No

Notes: Initial El Paso sampling of the combined cooling tower return line indicated a leak rate of 16 lbs/day of hydrogen sulfide and 7 lbs/day of benzene. Additional sampling was performed on the individual cooling tower return lines that combine to become the main line that was initially tested. Results from this additional sampling of the three individual lines showed no active leak. With this additional information, it was determined that there were issues with the original sampling of the combined return line. Therefore, no reportable quantities were exceeded as a result of this event.
151830

2013-10-22
No Information Given
Cause:

Followup: No

Notes: Initial verbal notifications were completed by K. Joseph to Louisiana State Police at 11:25am, LDEQ via SPOC, East Baton Rouge LEPC at 11:30, and the NRC at 11:35am. Due to prompt incident response to mitigate the event duration, no reportable quantities were exceeded.
9.0 pounds
150820

2013-09-04
No Information Given
Cause:

Followup: No

Notes: Due to prompt incident response to mitigate the event duration, we have determined that no reportable quantities were exceeded.
1.0 pounds
149414

2013-05-22
TGCU combuster (F-331)
Cause: On May 22, 2013 the Baton Rouge Refinery (BRRF) experienced an incident on the Tail Gas Clean-Up Unit (TGCU). The initial cause of the incident was due to a leak on the TGCU combustor (F-331). ExxonMobil received a compliance order (AE-CN-13-00463) from LDEQ authorizing interim emission limitations for the incident response, repair, and recovery. All community monitoring conducted by ExxonMobil were consistently below detection with the exception of a single monitoring hour on May 23, 2013. LDEQ's Mobile Air Monitoring Laboratory results were consistently below any concentration representing health concerns. The U.S. EPA contractor monitoring was consistent with BRRF monitoring efforts and results throughout the incident respose.

Followup: No

Notes: Upon discovery, ExxonMobil reduced Sulfur Plant (SRLA) feed rates to facilitate the transition to the F-101/F/-201 incinerators. This resulted in approximately 24 tons/day of potential sulfur dioxide being released. All emissions from this event will be provided int he follow-up reports as required per AE-CN-13-00436 Section IV and V. On May 24, 3012 at 10:30 p.m. a mechanical enclosure was installed on the combustor. Additional follow-ups will be provided in the reports as required per the compliance order. LABB has been unable to locate the follow up report with release amounts as of December 18, 2013.
146414

2013-02-02
storage tank
Cause: On February 2, 2013, a tank roof separated from the rim of tank releasing material to air. Initial contact with SPOC indicated a possible release exceeding 1 pound RQ limit of PAHs. The rim had separated from the roof of a storage tank at the facility. The tank was isolated. No estimate was available of how much material the tank contained. At approximately 5:08pm, Louisiana State Police was notified of a potential release of hydrogen sulfide over the reportable quantity.

Followup: No

Notes: Flow to the tank was shut off. SPOC states that caller reported 6ppm for VOCs during one update call.
145770

2013-01-07
Hydrocracker unit
Cause: There was a 3/4" pipe break in the Hydrocracker Unit.

Followup: No

Notes: Approximately 115 pounds of flammable vapor and less than 1 pound of hydrogen sulfide was released. Original SPOC notification states that more than 1000 lbs of flammable gas and more than 100 lbs of hydrogen sulfide were released, and that material did go offsite.
1.0 pounds
145716

2013-01-05
NIG
Cause: The release was caused by a control valve packing blow out.

Followup: No

Notes:
37.0 pounds
160151

2014-11-18
No information given
Cause: Release of flammable vapor, hydrogen sulfide and ammonia between 11/18 and 11/22. No information about accident cause given.

Followup: No

Notes:
294.0 pounds
159808

2014-11-01
Coker Unit
Cause: On 11/1/2014 at 1:50PM the safety valve in the west coker area (D101-A) lifted to the atmosphere for approximately four minutes then isolated. This event released 2 pounds of H2S and 171 pounds of flammable vapor.

Followup: No

Notes: Due to prompt incident response to mitigate the event duration, we have determined that no RQ's were exceeded.
2.0 pounds
159404

2014-10-10
No information given
Cause: Release of hydrogen sulfide on October 11, 2014. No information given about cause of accident.

Followup: No

Notes:
22.0 pounds
158761

2014-09-12
No Information Given
Cause: No Information Given

Followup: No

Notes: No Information Given
0.1 pounds
158694

2014-09-11
No Information Given
Cause: On Sept. 11, 2014, ExxonMobil Refinery had a release of hydrogen sulfide when a pump seal blew out on a unit. Release of 0.23 lbs of hydrogen sulfide. Initial report to state police hazmat hotline states that refinery is "unsure of what cause[d] seal to blow".

Followup: No

Notes: No Information Given, prompt incident response mitigated the event duration.
0.2 pounds
155266

2014-04-15
Cooling Water Tower
Cause: On 04/15/2014 at 11:19, ExxonMobile received a high reading on a cooling tower water sample. A follow up letter from refinery on 04/22/2014 indicates that release was below reportable quantity

Followup: No

Notes: No information given. ExxonMobile designated event as non-emergency release.
153389

2014-01-14
NIG
Cause: On January 14, 2014, a release of benzene and hydrogen sulfide was released.

Followup: No

Notes: Only document related to accident that LABB has access to is a one-page refinery letter dated January 21, 2014.
0.0 pounds