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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 | Release FLARE-Flare #5,8,9,17,23 | 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 information given/leak no informaiton 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 unspecified flares 7 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 valves pressure relief valve | 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 | valve at the HCLA unity C-102B compressor 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 | Furnaces, Incinerators Crude Tanks | 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 | Furnaces, Incinerators Crude Tanks | 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 |
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