Home Search Emissions Pollutants About the Database


ExxonMobil Refinery (2638), Baton Rouge

Causal Factor: Equipment Failure

LDEQ Accident Number
Accident Date
Point Source(s) Notes Amount of Release
No LDEQ Reported

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
Hydrogen Sulfide: 871.0 pounds
Volatile Organic Compounds: 8,512.0 pounds
Benzene: 58.0 pounds
1,3-Butadiene: 13.0 pounds
No LDEQ Reported

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
Hydrogen: 45.0 pounds
Hydrogen Sulfide: 13.0 pounds
Ammonia: 1.0 pounds
Methane: 500.0 pounds
Ethane: 1,753.0 pounds
Propane: 963.0 pounds
Isobutane: 107.0 pounds
n-Butane: 119.0 pounds
Isopentane: 17.0 pounds
n-Pentane: 7.0 pounds
88286

2007-07-05
No. 2 Fluid Catalytic Cracking Unit (PCLA-2) F-201 blowers (A and B)
Cause: the failure of the blower damper in the No. 2 Fluid Catalytic Cracking Unit caused the unit to unexpectedly shutdown.

Followup: No

Notes: This event was not preventable because there was no indication during the test the previous month that the damper would fail to open properly. Remedial Measures - this event was not preventable is what is stated in this section.A routine maintenance test was being performed on the No. 2 Fluid Catalytic Cracking Unit (PCLA-2) F-201 blowers (A and B). During this test the damper on the B blower failed to open correctly. Because the damper did not open correctly, the furnace sown due to loss of flame. Attempts were made by the assistant operator performing the test to immediately restart the furnace. This was not possible so the B blower was shut down and the A blower restarted. This allowed the furnace to be restarted wi

89401

2007-07-05
Motor Feed Pump on the No. 3 Fluid Catalytic Cracking Unit
Cause: pump failure. The main motor operated feed pump tripped off at the No. # Fluid Catalytic Cracking Unit. The turbine kicked in however failed to pump the rate required to keep the unit steady. As a result, the preheat furnace tripped due to low flow and the reactor temp. began to fall due to a lack of heat inpu

Followup: No

Notes: This incident was not preventable because there were no indications that the motor pump would fail. Remedial Measures - mechanical personnel will evaluate the turbine system to determine if the feed surge caused by the turbine can be prevented. During the Upset, the MACT II hourly limit for carbon monoxide and the maximum hourly permit limit and the maximum hourly concentration limit for carbon monoxide from 63 CFR Subpart UUU were exceeded at the WGS.The failure of the feed pump is covered undhe unit's Startup, Shutdown, Malfunction Plan and is considered a malfunction. Likewise, the exceedance of the permit limit is considered an Upset pursuant to LAC 33:III.507.J. and thus ExxonMobil claims the Upset Provision affirmative defense pu
Carbon Monoxide: 1,210.0 pounds
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
Nitrogen Oxide: 80.0 pounds
Sulfur Dioxide: 1,743.0 pounds
Nitrogen Dioxide: 14.0 pounds
Hydrocarbon: 465.0 pounds
Hydrogen Sulfide: 5.0 pounds

Butene: 16.0 pounds
Ethylene: 1.0 pounds
Propylene: 11.0 pounds
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.
Sulfur Dioxide: 593.0 pounds
Nitrogen Oxide: 27.0 pounds
Hydrocarbon: 158.0 pounds
Hydrogen Sulfide: 2.0 pounds
Nitrogen Dioxide: 5.0 pounds

Butene: 5.0 pounds
Propylene: 4.0 pounds
89742

2006-07-05
Check Valve on the Fluid Catalytic Cracking Unit
Cause: -during a routine maintenance check of the boiler feed water circulation pumps on the F-301 furnace, a check valve failed to function properly. As a result, the turbine operating the feed pump tripped off and the boiler feed water flow to the furnace was lost

Followup: No

Notes: This incident was not preventable because the failure of the check valve to function properly was not expected, and there were no indications that this valve might malfunction. Remedial Measures - the check valve will also be replaced on the sistertrain for F-201. The carbon monoxide maximum hourly permit emission limit and the maximum hourly concentration limit from 63 CFR Subpart UUU were exceeded. The MACT II hourly limit for carbon monoxide and the maximum hourly permit limit for carbon mode were exceeded at the WGS. However, because the failure of the check valve is covered under the unit's Startup, Shutdown, Malfunction Plan and is considered a malfunction, the exceedance of the permit limit is considered an Upset pursuant to LA
Carbon Monoxide: 1,011.0 pounds
90822

2006-07-05
F-201 Furnace
Cause: during a routine maintenance check of the air feed system on the F-201 furnace, air flow into the furnace was unexpectedly lost when an air louver failed to open

Followup: No

Notes: This incident was not preventable because the failure of this system was unexpected and there were no known indications that this system would fail. Remedial Measures - an investigation is ongoing and the appropriate follow-up actions will be completed. During this Upset, the MACT II concentration limit for carbon monoxide and the maximum hourly permit limit for carbon monoxide were exceeded at the wet gas scrubber. The failure of the air feed system is covered under the unit's Startup, Shun, Malfunction Plan and is considered a malfunction. The exceedence of the permit limit is considered and upset pursuant to LAC 33:III.507.J. Exxon intends to claim the Upset Provision affirmative defense pursuant to LAC 33:III.507.J. Carbon Monoxide
Carbon Monoxide: 2,529.0 pounds
87643

2006-05-02
Sample Cooler
Cause: process continued to try to find the source of the leak, which was originally thought to be two exchangers but was later found to be coming from a sample cooler

Followup: No

Notes: The accident was not preventable because there were no previous leaks on this exchanger (is an exchanger the same as the above sampling cooler? - where did the leak actually come from?). Remedial measures - the leaking cooler is being removed from service. LDEQ reportable quantities exceeded for volatile organic compounds
Volatile Organic Compounds: 10,300.0 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
Hydrogen Sulfide: 83.0 pounds
Sulfur Dioxide: 8,171.0 pounds
Nitrogen Oxide: 11.0 pounds
Nitric Oxide: 11.0 pounds
Hydrocarbon: 98.0 pounds
85275

2006-01-20
MTBE Unit Exchanger E-557
Cause: MTBE Unit Exchanger was discovered to leaking into the condensate system causing vapor to flash off. 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-Methyl-2-Butene: 15.0 pounds
trans-2-Pentene: 5.0 pounds
trans-2-Pentene: 5.0 pounds


cis-2-Pentene: 3.0 pounds
Diisobutylene: 1.0 pounds



MTBE: 216.0 pounds
n-Pentane: 1.0 pounds


TAME: 25.0 pounds
TBA: 1.0 pounds
Highly Reactive Volatile Organic Compounds (HRVOCs): 16.0 pounds
Flammable Vapor: 275.0 pounds
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


Hydrogen Sulfide: 2.0 pounds
Ethylene: 2.0 pounds
Propylene: 26.0 pounds
Butene: 16.0 pounds
Xylene: 48.0 pounds
Toluene: 17.0 pounds
Benzene: 2.0 pounds
Hydrocarbon: 496.0 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.
Sulfur Dioxide: 1,423.0 pounds

Sulfur Dioxide: 1,424.0 pounds
100050

2007-10-09
FLARE-Flare #5,17,19,20,24
Cause: air supply line broke

Followup: Yes

Notes: feed to both PCLA units were reduced. Air to the regenerator was adjusted to increase CO concentration in the flue gas and return CO combustion to the normal level in furnace.
Nitrogen Oxide: 17.0 pounds
Sulfur Dioxide: 1,139.0 pounds
99175

2007-09-05
oil spill
Cause: sample point on tank was halfway open

Followup: Yes

Notes: The sample point on tank was closed and efforts to recover oil began immediately
Oil: 2,957.0 gallons
99194

2007-09-04
FLARE-Flare #5,9,17,23
Cause: cooling tower pumps shut down due

Followup: No

Notes: The cooling tower pump was restarted to restore cooling water to the unit. The speed control was repaired after it caused the unexpected shutdown.
Hydrocarbon: 250.0 pounds
Butane: 96.0 pounds
Nitrogen Oxide: 62.0 pounds
98423

2007-08-04
Air blower malfunction
Cause: atlernate blower did not supply air to furnace

Followup: Yes

Notes: Airflow to the furnace was reestablished. Investigation is ongoing, necessary follow up procedures will be complete
Carbon Monoxide: 28,760.0 pounds
96828

2007-06-06
Flare
Cause: cooling tower pump failed

Followup: No

Notes: Several units were shut down to avoid a serious safety incident or property damage. The pump was repaired and returned to service
Nitrogen Dioxide: 29.0 pounds
Nitrogen Oxide: 209.0 pounds
Sulfur Dioxide: 14,921.0 pounds
Hydrocarbon: 835.0 pounds
Benzene: 32.0 pounds
95842

2007-05-02
Flare
Cause: broken air supply line was closed to control valve

Followup: No

Notes: Closed valve was bypassed until repairs,it was then replace
Hydrocarbon: 1,033.0 pounds
Butene: 496.0 pounds
Nitrogen Dioxide: 29.0 pounds
Nitrogen Oxide: 170.0 pounds
94413

2007-03-07
furnace permit deviations
Cause: valve misalignment

Followup: Yes

Notes: Once alignment was noticed, hydrogen sulfide stream was blocked from the high pressure burner line. 8 furnaces were involved(F1-4 at Powerformer2, F-31 at Feed Prep, F1 at 4-Light Ends East, F1-2 at 4-Light Ends Wes
Sulfur Dioxide: 1,054.0 pounds
94118

2007-02-22
Spill
Cause: safety valve was blocked causing steam to have flange undergo thermal expansion

Followup: No

Notes: Valve blocking the outlet of the pressure release valve was opened. All valves in similar service will be checked and contaminated soil was disposed of.
Gas Oil: 58.0 gallons
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.
Flammable Vapor: 1,731.0 pounds
Hydrogen Sulfide: 1,038.0 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.


111426

2008-12-15
PCLA Furnace F-301
unspecified flare
Cause: The refinery PCLA furnace F-301 developed holes in it which caused a release of 421 pounds of sulfur dioxide/day. On the same day, a flaring incident released 107 pounds of sulfur dioxide. Combined, these two sources released 528 pound of sulfur dioxide which is above RQ. The flaring incident occurred due to the depressurizing of the Alky unit for mechanical work after an unexpected shutdown. The unit was depressured after shutdown. This was an unplanned shutdown, which resulted in more light hydrocarbon loading for the vapor recovery system. The vapor recovery system was subsequently overloaded, resulting in a flaring incident. This incident was caused by a process upset.

Followup: No

Notes: Additional cooling tower cells started and rebalanced operations to reduced gas sent to the vapor recovery system. SO2 was leaked at a rate of 421 pounds per day from the furnace failure, but no information given as to the duration of the incident. Combined with the flare SO2 release, this incident surpasses the 500 pound RQ for SO2.
Sulfur Dioxide: 107.0 pounds
Sulfur Dioxide: 421.0 pounds
110703

2008-11-10
reactor 301 in LELA unit
Cause: According to the LDEQ incident report, reactor 301 in LELA unit has an ongoing leak.

Followup: No

Notes: Release is BRQ, but no information provided regarding when the ongoing leak was secured or what material was released.

110601

2008-11-05
Furnace F-301
Cause: Multiple holes have developed in the F-301 CO furnace box at the Catalytic Cracking Unit. The initial leak rate evaluation was completed 07/28/08 and SO2 emissions were BRQ. However on 11/5/08, the number of holes and hole size increased, and SO2 emissions were 726 pounds a day which exceeds RQ. On 11/21/08, the SO2 emissions reduced to 566 pounds a day which still exceeds RQ. On 12/5/08, the SO2 emissions were BRQ at 493 pounds/day. On 12/9/08, emissions reduced to 421 pounds per day. No further work will be perform on furnace due to the locations and personnel exposure of the remaining leaks. Air monitoring for SO2 was conducted at the furnace and near the fenceline after the RQ was exceeded. Readings of 13ppm, 25ppm, and 85ppm SO2 were detected at various levels 1 foot away from the furnace. Fenceline readings were all below detectable limits.

Followup: Yes

Notes: The lower temperature exposure and several of the higher temperature areas were patched to reduce the SO2 emissions to BRQ. The F-301 furnace will be shut down and repaired during the turnaround which is scheduled to begin January 2009. This release is RQ and ongoing.
Sulfur Dioxide: 19,395.0 pounds
110554

2008-11-01
NIG
Cause: According to the LDEQ incident report, a small pinhole leak in the alkylation caused a release.

Followup: No

Notes: The release of an unspecified material was BRQ.

110370

2008-10-26
NIG
Cause: According to the LDEQ incident report, a containment device bolt developed a leak and released a mixture of benzene and flammable gases.

Followup: No

Notes: Release is BRQ.


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.

109031

2008-09-13
Pipestill #10 tower
Cause: According to the LDEQ incident report, a leak in the Pipestill #10 tower spilt material on to concrete.

Followup: No

Notes: Water spray applied to knock down vapors. Some vaporized from the tower to air. Benzene and xylene were involved and initially reported as above reportable quantity. Exxon flared material for 29 minutes from the tower to isolate and make needed repairs.



108033

2008-08-13
safety valve release
Cause: Equipment failure-valve blocked

Followup: Yes

Notes: a pressure indicator and associated alarms will be installed on the line to prevent a similar overpressure incident from occuring.
Hydrogen: 11,866.0 pounds
Methane: 8,244.0 pounds
107535

2008-07-26
F-4 furnace
Cause: F-4 furnace in the Powerformer is leaking six drops per minute.

Followup: No

Notes: Drops have some gasoline components. A steam lance is being put on the head of the furnace.

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
Hydrocarbon: 93,672.0 pounds
Hydrogen Sulfide: 3,415.0 pounds
Sulfur Dioxide: 163.0 pounds
Nitric Oxide: 7.0 pounds
Benzene: 275.0 pounds
Hydrogen: 10,147.0 pounds
Methane: 5.0 pounds
n-Hexane: 683.0 pounds
Cyclohexane: 57.0 pounds

106230

2008-06-06
Furnace emmision deviation
Cause: The hydrogen sulfide analyzer for the NSPS fuel gas system indicated that the hydrogen sulfide levels in the fuel gas system increased. It was not initially known if the analyzer reading was accurate because there was no alarm indication for the operator of any unit malfunction that could have caused the elevated hydrogen sulfide levels. The source of the high hydrogen sulfide was due to a valve misalignment on the T-301 MEA scrubber at the #2 Light Ends Unit. Sour gas was inadvertently lined up through the scrubber, which had been down for repairs, without introducing MEA into the tower. The unscrubbed gas entered the NSPS fuel gas system and caused 33 furnaces in the NSPS system to exceed their maximum permitted limits for sulfur dioxide.

Followup: Yes

Notes: The high hydrogen sulfide stream was blocked away from the scrubber and the hydrogen sulfide level in the NSPS system dropped below the maximum allowable limit.
Sulfur Dioxide: 1,255.0 pounds
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.
Hydrogen Sulfide: 100.0 pounds
105933

2008-05-25

Cause: SPOC report states far east coker drum # 501 developed a leak on the thermal well (looks cracked).

Followup: No

Notes: SPOC report states a steam hose was put on leak. Batch process lasts until around 4, the leak will then be stopped and they will be able to access the crack.


105886

2008-05-23

Cause: One of the vapor release points on tank #100, containing feed oil, opened.

Followup: No

Notes: The tank has a natural gas blanket. It is slowly leaking into the atmosphere. They have a valve they have attempted to close. They believe it has been closed and are waiting to see if there are any more leaks.

105814

2008-05-21

Cause: There is a small leak around the thread of an orifice nipple that goes to a block valve.

Followup: No

Notes: It will take a while to fix the problem. Maintenance was on the scene trying to evaluate the problem when SPOC report was released.

105713

2008-05-19
no informaiton given/leak
Cause: Catylitic caustic scrubber in Merox unit leaked from an underground line, resulting in a release of a catalyst solution.

Followup: No

Notes: incident report due to potential impact to public due to the close proximity to railroad. Material did not leak to rail line. Update- cobalt contained in catalytic reagent determined not to be radioactive. Remediated by mixing with sand, shovelled up and placed in labeled drum

105373

2008-05-06

Cause: Pinhole leak from a tower is causing a release.

Followup: No

Notes: Tower was shut in for turn around but it still had pressure. At time, they would not be able to relieve pressure from the tower.

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
Hydrocarbon: 108.0 pounds
Hydrogen Sulfide: 4.0 pounds
Sulfur Dioxide: 1,445.0 pounds
Nitric Oxide: 68.0 pounds
Nitrogen Dioxide: 12.0 pounds

Methane: 4.0 pounds
104820

2008-04-16

Cause: There was a leak into the boiler feed water system at the far east coker unit.

Followup: No

Notes: They were attempting to isolate the source. Amount of PAH's and VOC's released is estimated at 2 barrel.


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
Hydrocarbon: 99.0 pounds
Hydrogen Sulfide: 1.0 pounds
Sulfur Dioxide: 372.0 pounds
Nitric Oxide: 17.0 pounds
Nitrogen Dioxide: 3.0 pounds

Butene: 3.0 pounds
Propylene: 2.0 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
Hydrocarbon: 98.0 pounds
Nitrogen Oxide: 17.0 pounds
Hydrogen Sulfide: 1.0 pounds
Sulfur Dioxide: 367.0 pounds
Nitrogen Dioxide: 3.0 pounds

Butene: 3.0 pounds
Propylene: 2.0 pounds
111957

2008-01-11
flare and PCLA F-301/F-201 furnace
Cause: Emergency isolation valve on GLA-2X compressor failed to close. This caused pressure build up in PCLA system, in which the control valve routed the excess gas to the flare system.

Followup: No

Notes: Under investigation. Exceeded RQ due to the combination from the flare and the PCLA F-301/F-201 furnace leaks (LSP Incident #08-07087).
Sulfur Dioxide: 633.0 pounds
119501

2009-11-16
flares
Cause: Compressor tripped at RGC unit.

Followup: No

Notes: RQ not exceeded. Will re-start compressor and minimize gas that will be sent to the flare.



118656

2009-10-11
No Information Given
Cause: Hydrogen compressor for the hydrocracker had a bladder rupture.

Followup: No

Notes: RQ not exceeded. Situation secured.

117931

2009-09-13
Flare #17 and #19
Cause: A problem with the hydrocracking unit caused flaring.

Followup: No

Notes: Release is BRQ. No further information provided.

117482

2009-08-25
FLARE
Cause: Hydrogen compressor leaked which caused flaring.

Followup: No

Notes: Release is BRQ. Compressor was de-pressurized to stop flaring.

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.




117187

2009-08-10
cooling tower
Cause: A cooling tower leaked propane.

Followup: No

Notes: Release is BRQ. Fixed leak.

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.

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.



116430

2009-07-14
unspecified flare
Cause: Coker compressor failed which caused flares to burn.

Followup: No

Notes: RQ not exceeded.

114733

2009-05-07
bypass stack
Cause: The Wet Gas Scrubber had a malfunction which led to failure of an expansion joining at CO Furnace, F-301. The malfunction required venting of PCLA 2 and 3 to bypass stacks and shutdown of Wet Gas Scrubber.

Followup: Yes

Notes: This incident exceeded RQs. PCLA-3 vented to bypass stack until shutdown was completed. All of the Wet Gas Scrubber nozzles were replaced. Root cause is under investigation.
Nitrogen Oxide: 5,819.0 pounds
Flammable Vapor: 23,643.0 pounds
Sulfur Dioxide: 115,215.0 pounds
113891

2009-04-01
unspecified flare
Cause: Flaring was caused by an overhead condenser leak at the PCLA complex. The overhead material at the PCLA fractionator is cooled using cooling tower water. A leak developed in these condensers which caused cooling tower water to enter the shell side of the overhead condensers. When the cooling tower water evaporated, salts and foulant were deposited in the process side of the overhead condensers, causing an increase in pressure drop. This increase in pressure drop caused the fractionator pressure to increase, and eventually exceed the set pressure of the pressure relief valves. The pressure relief valves released fractionator overhead into the flare gas recovery system, resulting in flaring. Sulfur Dioxide was released to the atmosphere in exceedance of the reportable quantity.

Followup: No

Notes: Unit pressure and unit feed rates were reduced to minimize overhead gas rates and eliminate flaring. Release exceeds RQ.
Sulfur Dioxide: 857.0 pounds
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.
Sulfur Dioxide: 978.0 pounds
Hydrogen Sulfide: 2.6 pounds
Nitrogen Oxide: 49.8 
Nitrogen Dioxide: 8.5 
113408

2009-03-15
#44 cooling tower
Cause: Leak in #44 cooling tower. Foaming occurred.

Followup: No

Notes: LABB only has access to the SPOC verbal report. No information provided about amount of material released, and the chemicals are unknown. There is a potential for VOCs released.

113123

2009-03-04
No Information Given
Cause: According to SPOC verbal report, a leak occurred on CO furnace.

Followup: No

Notes: RQ not exceeded.

112781

2009-02-16
No Information Given
Cause: According to the SPOC verbal report, a leak from the bottom of a tank caused the release.

Followup: No

Notes: Release is BRQ.









112424

2009-02-01
No Information Given
Cause: According to the SPOC verbal report, after an internal odor complaint, a reboiler leak was discovered.

Followup: No

Notes: The leak is still under investigation. Release is BRQ.

126044

2010-08-30
west coker
Cause: Strainer developed a leak at west coker.

Followup: No

Notes: This release was BRQ.
Oil: 19.0 gallons
Benzene: 10.0 pounds
125230

2010-07-28
Heat Exchanger
Cause: "Heat exchanger leak at the head and solvent naphtha is leaking. Depressurized to stop it."

Followup: No

Notes: BRQ. No information given.

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.



122839

2010-04-19
no information given
Cause: During start up of a unit, foam was discovered in a cooling tower which indicates a leak of VOCs. Investigation is going on to determine which heat exchanger was leaking VOCs.

Followup: No

Notes: No RQs exceeded. LABB only has access to the LDEQ incident report.

135328

2011-11-16
Broken Valve: Oil mist tank
Cause: On November 16th, 2011, at approximately 1:45 pm, there was a release to soil at the ExxonMobil Baton Rouge Refinery. A controller received a low pressure alarm on the oil mist system, and immediately investigated the source of the alarm. It was discovered that the support structure on the south side of the oil mist tank had collapsed. This resulted in the 1/2 inch bottom valve connection of the level gauge breaking. The level gauge was located on the side of the tank that tilted when the support rack collapsed. Approximately 350 gallons of lube oil was spilled. All material was contained onsite.

Followup: No

Notes: Upon discovery, the broken valve was immediately repaired, and the tank is being temporarily supported until permanent repairs are complete. Soil remediation is complete.
Lubricating Oil: 348.6 gallons
135091

2011-11-03
Exchanger (unspecified location)
Cause: An exchanger is leaking and Exxon is currently assessing the situation to determine how to correct.

Followup: No

Notes: They assessed the situation and determined how to correct it. No detailed information given regarding remedial actions.
Volatile Organic Compounds (VOCs): 43.0 pounds
134671

2011-10-07
C-102A and C-102B
Cause: On 10/7/11 at approximately 12:50 am, the Baton Rouge Refinery discovered a release. A controller noticed that the discharge temperature for hydrogen make-up compressor C-102A was increasing, so the compressor was shut down. Operations personnel were dispatched to investigation, whereby they discovered that the compressor had developed a leak. The emergency isolation valves were activated, and the leak was subsequently isolated. The leak was later determined to be from the #2 cylinder head. Approximately 881 lbs of flammable vapor were released. An iNotification was sent at 1:27 am as a precaution. The event was downgraded at 1"37 am, and the close out notification was sent at 2:11 am. During the same 24 hour period, hydrogen make-up compressor C-102B had an ongoing make-up hydrogen leak from a cylinder packing. This event release approximately 182 lbs during the 24 hour period. Combined, the two events resulted in an exceedance of the flammable vapor reportable quantity.

Followup: No

Notes: #2 Cylinder head leak. To end the release, the compressor was shut down and isolated. To prevent recurrence, the compressor will be repaired before being restarted. Weather conditions during the event: 69 degrees, 9.5 mph from the east, no precipitation.
Flammable Vapor: 1,063.0 pounds
134102

2011-09-19
Tank 717
Cause: On September 19th, 2011, at approximately 7:40 pm, there was an oil spill to soil at the ExxonMobil Baton Rouge Refinery. Oil was discovered on the ground South of Tank 717 on the Ketone Dewaxing Unit, and initial investigation revealing that a battery limit block valve had developed a leak. The amount released to soil was approximately 7.8 barrels of Foots Oil, all of which was contained on site. This spill resulted in an exceedance of the LDEQ reportable quantity for oil to soil.

Followup: No

Notes: The line was isolated to prevent further release. Vacumm trucks were used to remove oil, and absorbent pads were used to collect oil. The valve will be replaced before returning the line to service. Remediation in underway, and no groundwater impacts are expected.
Neatsfoot Oil: 319.2 gallons
133049

2011-08-10
storage tank
Cause: A storage tank has some pinhole leaks in the top which allowed vapors to escape from the top of the tank.

Followup: No

Notes: No RQs were exceeded as a result of this event.
Flammable Vapor: 182.0 pounds
132573

2011-07-19
dock berth #2
Cause: Oil was released from a steam tracing line that runs through dock loading arms' drain pan into the Mississippi River. Oil had inadvertently entered the steam tracing, and when the tracing was opened to remove condensate from the system, the oil was released and deflected to the water.

Followup: No

Notes: Booms were used to isolate the area and absorbent pads were used to remove the oil from surface water. The oil was collected, and no groundwater impacts are expected. Future steam tracing will be oil free before returning to service.
Oil: 0.1 gallons
132125

2011-06-29
FLARE: C-50 Flare gas recovery compressor
Cause: On 6/29/11, Exxon Refinery experienced a compressor malfunction. Operations personnel at the #2 Light Ends Unit discovered a vapor release from the C-50 flare gas recovery compressor due to a missing jackbolt. This release lasted 10 minutes. Additionally, RHLA-1 unit experienced a release from the channel box of exchanger E-700F. Emissions from this release are currently estimated to be 704 pounds per 24 hours. This release, however, is ongoing.

Followup: No

Notes: The compressor was isolated and depressurized to end the vapor release. Removing C-50 from service resulted in reduced flare gas recovery capacity, and flaring ensued. Evacuating C-50 of vapor also resulted in flaring. The spare compressor, C-40, was started once C-50 was secured to end the event. To end the vapor release, the compressor was isolated. To end the flaring, the spare compressor was started. Additionally, development and execution of a plan to repair the 2nd release is underway. Both of these release are above reportable quantity.
Sulfur Dioxide: 1,428.0 pounds
Flammable Vapor: 1,421.0 pounds
131902

2011-06-21
Bleeder pump P-105 and exchanger E-700F
Cause: On June 21st, 2011, at approximately 6:34 am, the Baton Rouge Refinery experienced a release. Operations personnel at the Alky unit discovered a bleeder on pump P-105 suction line releasing caustic, propane, and isobutane. Caustic is used throughout the refinery to remove sulfur compounds from the hydrocarbon streams, and a pressure gauge located on the suction line at this bleeder. The nipple connecting the pressure gauge to the suction line had worn threads, allowing the gauge to become disconnected from the piping system. All caustic was contained on concrete and did not reach the environment. Approximately 1,923 pounds of vapor were released. Additionally, during the same twenty four period, the RHLA-1 unit experienced a release from the channel box of the exchanger E-700F. Emissions from this release are currently estimated to be 704 pounds per 24 hours. Development of a plan to repair this release is underway.

Followup: No

Notes: To end the P-105 release, the bleeder was closed and the pump suction line isolated. To prevent recurrence, the bleeder will be repaired before being returned to service. Additionally, bleeders in similar service will be evaluated for similar leak potential by x-ray inspection.
Flammable Vapor: 2,627.0 pounds


131866

2011-06-16
Cooling tower CT-39
Cause: High indications of hydrocarbons while doing routine sampling of cooling tower water. Heat exchanger has a leak in it - Cooling Tower 39.

Followup: Yes

Notes: The refinery states that four separate incident report numbers were issued as ExxonMobil updated agencies of the leak resolution. Incident report numbers are - 131613, 131831, 131866 and 132049. The LDEQ report states that they received updates on the leak until June 24th on the status of the leak, at which point it was "identified and corrective action was taken. However, a July 21st refinery letter states that the leak was resolved by June 18th.

131831

2011-06-14
Cooling tower CT-39
Cause: High indications of hydrocarbons while doing routine sampling of cooling tower water. Heat exchanger has a leak in it - Cooling Tower 39.

Followup: No

Notes: The refinery states that four separate incident report numbers were issued as ExxonMobil updated agencies of the leak resolution. Incident report numbers are - 131613, 131831, 131866 and 132049. The LDEQ report states that they received updates on the leak until June 24th on the status of the leak, at which point it was "identified and corrective action was taken. However, a July 21st refinery letter states that the leak was resolved by June 18th.

131613

2011-06-07
Cooling tower CT-39
Cause: High indications of hydrocarbons while doing routine sampling of cooling tower water. Heat exchanger has a leak in it - Cooling Tower 39.

Followup: Yes

Notes: BRQ. The refinery states that four separate incident report numbers were issued as ExxonMobil updated agencies of the leak resolution. Incident report numbers are - 131613, 131831, 131866 and 132049. The LDEQ report states that they received updates on the leak until June 24th on the status of the leak, at which point it was "identified and corrective action was taken. However, a July 21st refinery letter states that the leak was resolved by June 18th.

131058

2011-05-05
Coker unit
Cause: The coker unit lost a compressor resulting in a release of sulfur dioxide.

Followup: Yes

Notes: Electrician corrected the problem on site within 5 minutes. Follow-up Letter corrects the inaccurate incident date from the original incident report from the refinery.

130721

2011-04-18
Leak in HCLA unit
Cause: Hydrogen release from a leak in the HCLA unit.

Followup: No

Notes: The HCLA unit was depressurized to stop the leaking.

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.
Hydrogen Sulfide: 100.0 pounds
1,3-Butadiene: 10.0 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.
Hydrogen Sulfide: 2.0 pounds
Ammonia: 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.
Ammonia: 2.0 pounds
Hydrogen Sulfide: 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.
Sulfur Dioxide: 382.0 pounds





133503

2011-03-22
Exchanger on KDLA unit, tower #22
Cause: An exchanger on the KDLA unit, tower #22 is leaking VOCs.

Followup: No

Notes: The exchangers were isolated and tested to find the leak. The initial sample results were erroneously high and no reportable quantities were exceeded.

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.
Hydrogen Sulfide: 2.0 pounds
Volatile Organic Compounds (VOCs): 1,912.0 pounds
Propylene: 122.0 pounds

129115

2011-02-05
Tank 101: Water Clarifier Unit
Cause: LDEQ states that the wastewater tank developed a leak, leaking 1/2 gallon of wastewater per minute. Refinery letter identified material released as "primary sludge, hazardous waste F037." LDEQ notes contents of tank are a hazardous material. Exxon personnel pumped all water below the leak point and are working to repair tank.

Followup: No

Notes: RQ. Reportable quantities were exceeded. Contaminated soil was removed. The tank will be permanently repaired before being returned to service.
Primary Sludge: 403.0 pounds
129039

2011-02-03
Natural Gas Blanket System
Cause: The Natural Gas Blanket System failed. This caused the vents on the tank to over-pressure.

Followup: No

Notes: BRQ. Less than one thousand pound of flammable vapor was released. No information about remedial actions was given.

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."

Flammable Vapor: 234.0 pounds

128656

2011-01-18
Leak in Cooling Towers
Cause: Butane reading in cooling towers due to small leaks.

Followup: No

Notes: The releases were found during cooling tower sampling using the El Paso testing method. No RQs exceeded.

128384

2011-01-03
Flange
Cause: LDEQ states that hydrogen was released due to a fire on the flange.

Followup: No

Notes: BRQ. The fire was extinguished. The reactor that caught fire was depressurized. Refinery letter states that air monitoring was conducted during incident and all readings were below equipment detection limits.
Hydrogen: 18.0 pounds
128412

2011-01-03
No Information Given
Cause: LDEQ states that the leak occurred in a unit that caused an isobutane leak.

Followup: No

Notes: BRQ. Refinery letter states that due to prompt incident response, no reportable quantities were exceeded. The unit with the leak was shutdown.
Isobutane: 290.0 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.
Hydrogen Sulfide: 29.0 pounds
No LDEQ Reported

2012-10-01
Hydraulic hose on crane
Cause: While moving a welding machine with a crane on the Volks barge, the hydraulic hose on the crane developed a leak.

Followup:

Notes: ExxonMobil claims that Volks is the responsible party. The crane was owned and operated by Volks

141822

2012-08-03
Furnace F-334
Cause: A packing leak was discovered on the bypass valve at the furnace (F-334)at the Powerformer unit.

Followup: No

Notes: No reportable quantities were exceeded due to prompt incident response. States that approximately 730 lbs of flammable vapor and VOCs were released in this incident, but does not say if that is the combined amount, or if applies to both pollutants.
Flammable Vapor: 730.0 pounds
Volatile Organic Compounds (VOCs): 730.0 pounds
140306

2012-06-07
Tank #134
Cause: Cycle oil was leaking from the bottom of Tank #134 and into the soil.

Followup: No

Notes: The oil was pumped into another tank.
Diesel Fuel: 26.0 gallons
139107

2012-04-24
Leaking head on exchanger
Cause: A head on the exchanger leaked, and material was released to concrete and to the sewage catch basin.

Followup: No

Notes: The catch basin was damned off, and they vacuumed up the chemicals. Immediate and initial reports to the LDEQ hotline indicate that this accident released more than 10 pounds of benzene, 100 pounds of naphthalene, 100 pounds of cresol, and 100 pounds of biphenyl. Many of these are RQ. However, in the written report sent by ExxonMobil on 4/30/12, ExxonMobil has determined that no RQs were exceeded, and that only 28.9 gallons of crude oil was spilled due to prompt incident response to mitigate the event duration.
Crude Oil: 28.9 gallons
138623

2012-04-03
Coker unit #D-501-A
Cause: Flammable vapor was released after a small fire took place on coker unit #D-501-A. After the fire was extinguished a crack was discovered in the welding of the top head of the drum causing a leak. Venting release.

Followup: No

Notes: The fire was extinguished. To stop the leak, the facility personnel steamed the drum for 2 hours and then filled the drum with water for 4 1/2 hours until the leak was isolated. During isolation, perimeter air monitoring was conducted and there were non-detect values. ExxonMobil Refinery originally reported a release of over a 1000 lbs of flammable vapor being released with this event; however, on April 12, 2012 they informed the LDEQ that a total of approximately 42 lbs of flammable vapor was released. During the incident, although the material was going off-site, ExxonMobil only monitored the air quality inside the facility.
Flammable Vapor: 42.0 pounds
138347

2012-03-23
Cooling Towers 20 and 21
Cause: A leak in the exchanger released benzene from cooling towers 20 and 21.

Followup: No

Notes: Facility staff looked for and isolated the source of the leak. Sample results for the cooling tower were back to normal range. ExxonMobil initially reported that 10 pounds of benzene was released to an ongoing tower leak. High sample results were received for the tower. However, after further evaluation, the facility determined that no RQs were exceeded.

137655

2012-03-03
FLARE: Flares #19 and #17
Cause: The RGCU C-30 compressor shut down which resulted in flares #19 (2 minutes) and Flare #17 (1 minute) burning.

Followup: No

Notes: The scene was secured at time of notification or by 1335 on 3/6/12.
Sulfur Dioxide: 30.0 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.
Flammable Vapor: 3,753.0 pounds
Hydrogen Sulfide: 202.0 pounds
Benzene: 11.0 pounds
136643

2012-01-20
Cooling tower 35
Cause: In the initial report, sample results indicated a release of estimated 632 pounds of benzene due to a pressurized leak in the cooling tower. After further evaluation, ExxonMobil determined that the sample results were erroneously high and that there was no release to the cooling tower. Total Organic Carbon (TOC) levels were elevated to 31 ppm.

Followup: No

Notes: ExxonMobil's revised statement concerning the quantity released was based on the results that it gained from the El Paso cooling tower sampling method, an approved MACT CC compliance test method. EMBR states the results were erroneously high.

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.
Benzene: 17.0 pounds
Flammable Vapor: 5,073.0 pounds
Hydrogen Sulfide: 811.0 pounds
Sulfur Dioxide: 947.0 pounds
Volatile Organic Compounds (VOCs): 7,243.0 pounds
151115

2013-09-19
Reboiler
Cause: On September 19, Exxon Refinery had a release of VOC's caused by a leak in a reboiler to a low pressure condensate system.

Followup: No

Notes: Due to prompt incident response the mitigate the event duration, no reportable quantities were exceeded.
Volatile Organic Compounds (VOCs): 13.0 pounds
150748

2013-08-30
No Information Given
Cause: On August 30, ExxonMobil Refinery was depressurizing some equipment when they found 4 valve caps leaking.

Followup: No

Notes: Due to prompt incident response to mitigate the event duration, no reportable quantities were exceeded. Approximately 17 lbs of flammable vapor were released as a result of the incident.
Flammable Gas: 17.0 pounds
148914

2013-05-26
No Information Given
Cause: On May 26, 2013, there was a secured crude oil release to concrete slab at the ExxonMobil Baton Rouge Refinery.

Followup: No

Notes: The Refinery letter states that approximately 7 gallons of crude oil reached the soil, which resulted in less than 1 pound of benzene being released. The LDEQ Verbal Report states that the release was characterized as 30 gallons of crude oil and less than 10 lbs of benzene.The State Police Form shows an update in which total oil released was 32 gallons and total benzene released was 0.22 lbs.
Benzene: 1.0 pounds
Crude Oil: 7.0 gallons
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.


148249

2013-04-20
E-26-1
Cause: On April 20, 2013 at the Baton Rouge Refinery work was being conducted on the #8 Pipestill unit when a potential exchanger leak of crude oil underneath insulation was discovered on E-26-1. Upon further investigation during the next shift no leak source could be identified.

Followup: No

Notes: The initial refinery letter stated that the insulation on exchanger E-26-1 will be removed in the next four to six weeks (of April 25, 2013) to determine a potential leak source. The report indicates the quantity of volatile organic compounds to be undetermined, but does not suggest if the quantity released is below or above reportable quantity. At the time of the incident, the weather conditions were as follows: 71 degrees Fahrenheit with a 7 mph wind from the East and no precipitation. LABB has been unable to locate follow up reports providing further information.

147520

2013-03-22
Tank 711
Cause: On March 22, 2013, at approximately 18:50, there was an oil spill to soil at the ExxonMobil Baton Rouge Refinery. During routine unit rounds, oil was discovered pooled at the base of tank 711, which contained lube basestock. After further investigation, it was discovered that the underground sump suction line on the northwest side of tank 711 developed a pinhole leak. The amount released was approximately 5 barrels, all of which was contained on site.

Followup: No

Notes: Tank 711 was immediately emptied to isolate the leak, and a clam was installed on the line to stop the release. A vacuum truck was used to remove oil and soil remediation had been initiated. The weather conditions at the time of the spill were as follows: 71 degrees Fahrenheit, 12 mph winds from the Southeast with no precipitation.
Oil: 210.0 gallons
145716

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

Followup: No

Notes:
Hydrogen Sulfide: 37.0 pounds
Flammable Vapor: 275.0 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.
Hydrogen Sulfide: 2.0 pounds
Flammable Vapor: 171.0 pounds
155694

2014-05-01
Compressor in hydro cracker unit
Cause: A valve on a compressor leaked at the Hydro Cracker Unit.

Followup: No

Notes: Mechanics attempted to tighten the leaking valve.
Flammable Vapor: 456.0 pounds
155370

2014-04-20
compressor
Cause: The C-50 compressor at RGCU unit shut down, unexpectedly, releasing material into the flare gas system. This incident alone did not exceed any reportable quantity, however in conjunction with other ongoing releases, the reportable quantity for sulfur dioxide was exceeded.

Followup: No

Notes: Upon compressor shutdown, a secondary compressor was started. The incident is under investigation to determine the exact root cause and to provide mitigating steps to prevent recurrence.
Sulfur Dioxide: 594.0 pounds