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Valero (1238), Meraux
Releases in 2007
| LDEQ Accident Number Accident Date |
Point Source/Release | Cause | Notes |
| 101183 2007-11-09 | Point Source(s): Vacuum Truck - slop oil was spilled to unpaved ground water at the wastewater treatment sludge processing area. Pollutant(s):Slop Oil - 84 gallons | Cause of Problem: Equipment Failure incident occurred as a result of a faulty check valve - debris located in the suction valve seat allowed the valve to stay open when it should have been closed. When the tank pressurized, contents were blown out of the suction side of the system. The operator failed to ensure that the suction system was clean and operating properly before pressurizing the tank | This was a self-report from Murphy to LDEQ and they also followed up with written notice of the incident. The slop oil spill was to unpaved ground at the wastewater treatment sludge processing area. A vacuum truck driver loaded the slop oil from Tank 5-3 and proceeded to offload at the processing area releasing the material onto the ground. The spill impacted an area of approx. 30 feet by 50 feet and was contained in this one area. Murphy immediately responded by recovering approx. 85% of theliquids with vacuum trucks. The next morning, Murphy scraped up all visibly contaminated soil (approx. 3 cubic yards) for disposal at Waste Management's Woodside Landfill in Walker, LA. NOTE: The operator failed to ensure that the suction syste |
| 100603 2007-10-30 | Point Source(s): Malfunction at the offsite vendor facility which provides hydrogen to Murphy. (Could this be Air Products - see incidents # 93737, 98860, 99344, 99713) Pollutant(s):Sulfur Dioxide - 30 pounds | Cause of Problem: Process Upset On 10/28/2007, MOUSA conducted an emergency shut down of the #3 SRU after being forces to shut down the Hydrocracker (its source of acid gas) following a malfunction at the office vendor facility which provides hydrogen to MOUSA. There was no malfunction or human error on the part of Murphy. On 10/30/2007, MOUSA stared the #3 SRU back up following the above mentioned shutdown | This incident was not preventable because the shutdown of the hydrocracker and subsequent shutdown of the #3 SRU were the result of a malfunction at our offsite hydrogen vendor. BUT, the report says that yes, MOUSA could have attempted a startup without a bypass of the #3 TGT, but that MOUSA opted to use the safer TGT startup procedure of bypassing the TGT in order to better control Reactor Bed temperatures, which was more protective of personnel and equipment. The more aggressive startup optiif it had resulted in another exothermic reaction, could have damaged equipment and resulted in prolonged bypass of the #3 TGT, resulting in significantly greater sulfur dioxide emissions. Remedial Measures - MOUSA suspects that excess oxygen upset t |
| No LDEQ Number Available 2007-10-22 | Point Source(s): MOUSA - 20 Arpent Canal Pollutant(s):Oil - 3 gallons | Cause of Problem: Weather the sheen was a result of approximately 6-8 of heavy rainfa | The spill may have been less than 3 gallons because in Murphy's report they say it was 2-3 gallons of oil. The spill was located in the 20 Arpent Canal, west of the Meraux Canal. The offsite impact was below reportable quantities. Murphy deployed containment booms across the 20 Arpent Canal and recovered the free liquids with vacuum trucks. Murphy also notified the National Response Center and the U.S. Coast Guard on 10/22/2007 (NRC # 852-35 |
| 99900 2007-10-02 | Point Source(s): Waste Water Treatment Plant Pollutant(s):Butanol 2 - BRQ | Cause of Problem: No Information Given No Information Given - Odor | According to the Murphy report and the LDEQ report, Murphy had a slight odor estimated to be butanol #2 from the waste water treatment plant. At the same time there was a strong odor from a nearby marsh fire. LDEQ states that neither odor is actionable with regard to Murphy. The marsh fire was investigated and no responsible party could be found |
| 99867 2007-09-29 | Point Source(s): None Reported Pollutant(s): | Cause of Problem: Other Murphy experienced a supply problem with their purchased natural gas. This caused the flaring incident. | In the Murphy report, this incident is listed as odor, this was natural gas form Embride (unscented gas). In the LDEQ report, it explains that Murphy experienced a supply problem with their purchased natural gas and this caused a flaring incident. This incident was reported by several citizens but not by Murphy. It is a continuation of incident 9986 |
| 99828 2007-09-28 | Point Source(s): FLARE - the episode resulted from a valve misalignment involving the uncommanded closure of the SCOT inlet control valve, which triggered the unit's automatic Safety Instrumented Shutdown process. A root cause analysis concluded that a loose wir Pollutant(s):Sulfur Dioxide - 23,988 pounds | Cause of Problem: Other the episode resulted from a valve misalignment involving the uncommanded closure of the SCOT inlet control valve, which triggered the unit's automatic Safety Instrumented Shutdown process. A root cause analysis concluded that a loose wire tripped the fuse supplying power to the valve solenoid | This incident was not preventable because the loose wire occurred despite inspections made during routine maintenance and operator rounds. Remedial Measures - MOUSA is actively working to install redundant solenoids on this critical valve. SEE LDEQ reports # 99867, 9986 |
| 99713 2007-09-24 | Point Source(s): FLARE - Malfunction of Air Products Gas Oxygen Compressor / North Flare Pollutant(s):Sulfur Dioxide - 25 pounds | Cause of Problem: Process Upset a release to the North Flare in which process safety valve intermittently relieved pressure from the Area 6 Rich Amine Flash Drum. The unit was upset due to low hydrogen purity from Air Products due to a malfunction of their Gas/Oxygen Compressor. | In Murphy's report, they acknowledges that the Area 6 Rich Amine Flash Drum has been involved in two recent events - 8/23 and 9/10 but that improved monitoring systems have enabled MOUSA to more accurately estimated emissions. NOTE - the LDEQ report, which was made my Murphy, states that a hydrogen supply problem to the refinery and an faulty flow meter (which was replaced) were the causes of the release |
| 99344 2007-09-10 | Point Source(s): FLARE - Malfunction of Air Products Gas Oxygen (GOX) Compressor / South Flare Pollutant(s):Sulfur Dioxide - 9,557 pounds | Cause of Problem: Equipment Failure the incident was a result of light hydrocarbon contamination (methane) in the supply of pure hydrogen to MOUSA from Air Products resulting from a malfunction of their Gas Oxygen (GOX) Compressor. Hydrogen Purity abruptly dropped from 99.5% to approx. 95%. The methane flashed, exceeding the pressure setting on the relief valve from the Flash Drum to the Flare | This incident was not preventable because MOUSA was unable to predict the malfunction of the Air Products GOX compressor and was not provided timely notification of the problem. There was no malfunction or human error on the part of MOUSA. RemedialMeasures - In order to quickly detect and respond to such events, MOUSA gained access to the data from the Air Products online hydrogen purity analyzer on the supply line from Air Products. At the next unit turnaround, MOUSA will install a Rich Aminash Drum pressure indicator on the DCS console. MOUSA also developed an operating procedure to standardize the adjustments that must be made to quickly overcome such an event. The corrective actions listed above should enable MOUSA to provide timely |
| 98885 2007-08-24 | Point Source(s): Compressor at the Platformer Pollutant(s):Hydro-treated hydrocarbon - BRQ | Cause of Problem: Process Upset The compressor at the Platformer shut down for about 10 min.. And sent clean hydro-treated hydrocarbon to the flare. | There is no corresponding report from Murphy. In the LDEQ report, this event is described as a noise event. It states that there was smoke and noise but the combustion of the vented hydrocarbon was essentially total. According to the report, Platformer feed is very pure and all sulfur and nitrogen has been removed so these materials are not released when that hydrocarbon stream is directed to the flare. The noise came from the steam that allows this steam to burn smokeless. The complaint was cd in about seven min. into the event. NOTE - there is no information regarding why the compressor as the Platformer shut down in the first place? |
| 98860 2007-08-23 | Point Source(s): FLARE - Malfunction of Air Products Gas Oxygen (GOX) Compressor /South Flare Pollutant(s):Sulfur Dioxide - 19,000 pounds | Cause of Problem: Equipment Failure the incident was a result of light air hydrocarbon contamination in the supply of pure hydrogen to MOUSA from Air Products resulting from a malfunction of their Gas Oxygen (GOX) Compressor. The hydrocarbon impurities flashed, exceeding the pressure setting on the PSV from the Flash Drum to the Flar | This incident was not preventable because MOUSA was unable to predict the malfunction of the GOX compressor at the hydrogen vendor and was not provided timely notification of the problem. There was no malfunction or human error on the part of MOUSA. Remedial Measures - First, MOUSA worked with the Air Products to develop a communications system should they experience malfunctions in the future. Second, MOUSA developed an emergency procedure to react to such an event. Third, MOUSA developed impd monitoring of the flow rate off the PSV to more accurately estimate emissions from such an event. (Flow rate went off scale on the flow meter, so MOUSA re-ranged the meter. A similar event occurred on 9/24/2007 and data from that event suggested th |
| 98724 2007-08-16 | Point Source(s): DHT Sour Gas Compressor/ DHT Overhead Receinver Pollutant(s):Sulfur Dioxide - 261 pounds | Cause of Problem: Instrument Failure the incident was triggered by a faulty level reading in the DHT Overhead Receiver (reading 30% less than actual). The compressor shut down when the knockout pot downstream of the DHT Overhead Receiver alarmed on high liquid level. The level gauge apparently failed due to scale (rust) plugging the instrument. | The incident is listed as preventable even though the only information included in that section is that MOUSA did not anticipate the accumulation of scale during the extended shutdown of the vessel. Remedial Measures - the DHT unit had been shut down for 110 days. MOUSA is working on plans to prevent scale formation by securing the Overhead Receiver under an inert atmosphere in any future extended shutdowns. Note: the flare resulted from an automatic safety shutdown of the DHT Sour Gas Compre - but nonetheless, the incident was triggered by a faulty level reading in the DHT Overhead Receiver - the level gauge having failed due to scale (rust) plugging the instrument. |
| 98709 2007-08-16 | Point Source(s): FLARE - #3 TGT Bypass Pollutant(s):Sulfur Dioxide - 1,031 pounds | Cause of Problem: Process Upset This shutdown and the subsequent release can be attributed to a process upset. The incident occurred as MOUSA was troubleshooting deviant values in the air demand ratio as part of an effort to proactively diagnose potential problems in the unit. As MOUSA took a flow indicator offline to examine it, the air-to-fuel ratio drifted off-specification, triggering a safety shutdown of the unit on loss of flame in the TGT feed heater | There was a problem with the air demand ratio controller on the #3 Tail Gas Treater. While the company was troubleshooting the problem they placed the unit on manual control. The unit then proceeded to drift off of the settings and reached a condition where the unit took an automatic safety shutdown. The shutdown could probably have been averted if the ratio drift had been anticipated so this shutdown was due to an unanticipated process upset but the next time the ratio controller has a problem theany should be able to avert a shutdown by carefully monitoring the air demand ratio. - LDEQ report. This incident is listed as being preventable but the only information in that section is that MOUSA did not anticipate this event in the development o |
| 98371 2007-08-01 | Point Source(s): FLARE - Relief Valve on the MDH High Pressure Stripper / South Flare Pollutant(s):Sulfur Dioxide - 1,110 pounds | Cause of Problem: Process Upset on 8/3/2007, MOUSA discovered that a pressure relief valve on the MDH High Pressure Stripper was opening to the South Flare on an intermittent basi | This incident is listed as preventable even though the only information included in that section is that there were no mechanical failures or human error. MOUSA's report states that they suspect that ambient weather conditions (90 degrees, looping East wind at 0-5 mph) contributed to the episode, preventing typical dispersion of emissions to upper levels. Murphy received 3 citizen calls on 8/2/2007 for odor. They investigated each complaint and found transient odors consistent with trace ats of sulfur dioxide. They examined process conditions and found no upset conditions and no elevated levels of sulfur dioxide emissions from the facility - as noted by the numerous continuous emissions monitoring systems associated with heaters, boil |
| No LDEQ Number Available 2007-08-01 | Point Source(s): Gasoline Spill to River at Dock - transfer line/hose Pollutant(s):Benzene - 7 pounds Gasoline - 30 gallons | Cause of Problem: Equipment Failure During a test conducted at 188 psi, a rubber loading hose, rated for a pressure of 225 psi, developed a 4 inch long split, allowing gasoline to spray to the Rive | This incident occurred on 8/1/2007 and was not reported by Murphy until 3/11/2008. This incident was not preventable because the rupture of the hose was not a predictable event. At the time of the spill of 30 gallons of gasoline into the Miss. River, MOUSA was conducting annual pressure testing of a hard piped gasoline transfer line, per U.S. Coast Guard regulations. Because MOUSA was not loading gasoline to a vessel, the 8 rubber loading hoses at the Dock had been capped at the loadend, were elevated and suspended from their gantry hangers, and were secured from the loading hoses. During a test conducted at 188 psi, a rubber loading hose, rated for a pressure of 225 psi, developed a 4 long split, allowing gasoline to |
| 98214 2007-07-30 | Point Source(s): None Reported Pollutant(s): | Cause of Problem: No Information Given No Information Given | There is no corresponding report from Murphy. The LDEQ report states, No cause could be found for this incident. There was no record in the shift foreman's log book of a release to the flare at this time. No other information is provided |
| 98189 2007-07-27 | Point Source(s): None Reported Pollutant(s): | Cause of Problem: No Information Given No Information Given - Odor | There is no corresponding report from Murphy. The LDEQ report states, There was an upset at the Murphy wastewater treatment plant. This released an oily biomass smell that Matt Dobbins estimated to be about a 3 on a butanol scale. The odor wasfound by operating personnel and adjustments were made which eliminated the odors. There were no violations at the water outfall for the plant. No other information is provide |
| 97825 2007-07-12 | Point Source(s): Thermal Reactor Pollutant(s):Sulfur Dioxide - 113 pounds | Cause of Problem: Corrosion MOUSA shut down the #2 SRU in order to inspect a visible leak in the Thermal Reactor. MOUSA found localized corrosion damage to the shell resulting from acid gas infiltrating a small defect in the refractory. | This incident was not preventable because the leak in the Thermal Reactor was not a predictable event. Remedial Measures - MOUSA shut down the unit, conducted a thorough inspection, and patched the leak in accordance with API 510. MOUSA will repair the internal refractory during the next scheduled turnaround. MOUSA conducts routine on-stream ultrasonic inspections on this unit to monitor equipment fitness |
| No LDEQ Number Available 2007-06-26 | Point Source(s): #2 FCC Slurry Cooler Pollutant(s):FCC Slurry Oil - 15 gallons | Cause of Problem: Maintenance/Procedures the cause of the release was a leak in the #2 FCC Slurry Cooler during startup of the #2 FCC following a 30-day maintenance outage. | There is no information as to whether this event was preventable or not. Remedial Measures - The refinery and O'Briens Group deployed absorbent and hard booms to minimize the impact to the river. According to Murphy, there was no adverse impact to wildlife in the area. Within approximately 24 hours, Outfall 001 and the cooling water return pond were free of material. Representatives from USCG and LDEQ observed clean-up efforts on June 26 and 27. The FCC slurry leaked into the Mississippi R via Outfall 001 (Once Through Cooling Water discharge). The leak was discovered by visual inspection of the cooling water return pond |
| 96570 2007-05-29 | Point Source(s): High vibration trip in the HCU Recycle Gas Compressor Pollutant(s):Sulfur Dioxide - 789 pounds | Cause of Problem: Process Upset the startup of the #3 Sulfur Recovery Unit was a result of a shutdown of said unit which was the result of a lack of feed after an automatic safety shutdown of the Hydrocracker (high vibration trip in the HCU Recycle Gas Compressor). The vibration in the compressor was apparently due to surging in the unit during low flow conditions. | This incident was not preventable because the erratic performance was not a predictable event. Remedial Measures - MOUSA installed mechanical stops on the spillback valves to prevent erratic performance during low flow situations. MOUSA modified its startup procedure to eliminate the TGT Bypass. |
| No LDEQ Number Available 2007-05-25 | Point Source(s): #2 FCC Main Air Blower Lub Oil Cooler Pollutant(s):Lubricating Oil - 1 gallons | Cause of Problem: Piping or Tubing -the cause of the release was a leak that developed in the #2 FCC Main Air Blower Lube Oil Cooler - leaking tube | There is no information as to whether this accident was preventable or not. Remedial Measures -Sorbent booms were deployed in containment activities and a vacuum truck was used to recover the oil in the retention pond. According to Murphy, there was no adverse impact to wildlife in the area. Murphy Oil provided verbal notification to the SERC, USCG, and the NRC. This incident also involved the refinery's once-through cooling water discharge into the Mississippi River - the facility's cng water enters a retention pond prior to discharging into the Miss. River via Outfall 001. The leak was discovered by visual inspection of the retention pon |
| 96333 2007-05-18 | Point Source(s): #3 SRU Incinerator (#5-00) / South Flare (#3-77) Pollutant(s):Sulfur Dioxide - 15,688 pounds | Cause of Problem: Process Upset 5/18 shutdown of the #3 SRU which was the result of a lack of feed as MOUSA reduced feed to the hydrocracker and other units following a safety shutdown in the Crude Unit. MOUSA attempted to restart and line out units in the refinery and on 5/20 the #3 SRU unit shutdown after its source of acid gas, the Hydrocracker Unit, shutdown on 5/20 because of a malfunction at the Recycle Gas Compressor (high vibration) which triggered an automatic safety shutdown of the Hydrocracker. On 5/21 #3 SRU was started up and on 5/23 the #3 SRU experienced an automatic safety shutdown which was the result of a solenoid malfunction on the SCOT bypass valve (v-509), which failed to open while lining up the Tail Gas to the SCOT Reactor, per the startp plan. The # 3 | Even in the final 10/18/2007 follow up report Murphy does not explain whether the incident was preventable or not. Remedial Measures - Regarding the HCU shutdown, MOUSA installed a new probe to monitor vibration in the HCU Recycle Gas Compressor. Regarding the # 3 SRU malfunction, MOUSA has (1) replaced the solenoid on TB-NV-509, (2) modified the unit startup procedure to limit the recirculating gas rates through the startup blower just before diversion of the SRU tail gas to the Absorber Secof the Tail Gas Unit, (3) developed a Preventative Maintenance schedule to conduct inspections on the exhaust screens on critical solenoids in the #3 SRU, and (4) installed new logic to improve the coordination of the two valve actuators. Note: all |
| 96245 2007-05-16 | Point Source(s): Tank 20-1 at the MOUSA Meraux Terminal Pollutant(s):Benzene - 48 pounds n-Hexane - 26 pounds Cyclohexane - 24 pounds Isooctane - 9 pounds Toluene - 123 pounds Ethylbenzene - 32 pounds Xylene - 168 pounds 1,2,4-Trimethylbenzene - 47 pounds Gasoline - 18,900 gallons | Cause of Problem: Human Factors this episode was the apparent result of human error. The terminal received a transfer of gasoline from the Refinery via pipeline on 5/15, after which a Terminal Operator failed to follow written procedures to secure two valves that isolate the Terminal from the Refinery. The next evening, while the Refinery was loading gasoline at the river dock on the same pipeline, Tank 20-1 overfilled | There is no information as to whether this incident was preventable or not - I assume it was since it is due to human error that seems preventable. Remedial Measures - St. Bernard Highway and the adjacent rail line were closed until 7:30 (am or pm?) - Approximately 450 barrels of material was released from the tank into the diked containment area. MOUSA immediately shut down the loading operations to the Dock and initiated emergency response actions in accordance with the TerminalSPCC Plan. MOUSA secured the tank, deployed firefighting foam for vapor suppression, recovered free liquids with vacuum trucks, and will remove contaminated soil. Free liquids were returned to the refinery for re-processing. Contaminated spill respon |
| 96168 2007-05-12 | Point Source(s): High point vent valve on Tank 250-1 injection pump Pollutant(s):Crude Oil - 2,100 gallons | Cause of Problem: Equipment Failure the source of the spill was a high point vent valve that was left open on the Tank 250-1 injection pump. | There is no information as to whether this incident was preventable or not. Remedial Measures - Murphy Oil deployed containment booms and recovered the free liquids with vacuum trucks. Soil with signs of visual contamination is being removed for proper disposal. Note: could this be caused by human error???? |
| 95936 2007-05-04 | Point Source(s): Secondary containment area of Tank 80-7 Pollutant(s):#6 Oil - 168 gallons | Cause of Problem: Weather the spill was discovered on 5/5/2007 at 7:30. As a result of heavy rainfall on the afternoon of 5/4/2007, rainwater flowed into an open tank man way which had been removed for maintenance. The rainwater displaced some of the oil remaining in the tank resulting in the spill | There is no information as to whether this incident was preventable or not. Remedial Measures - Murphy Oil recovered the free liquids with a vacuum truck. Soil with signs of visual contamination is being removed for proper disposal. According to the LDEQ report, Stephen Faller of Murphy Oil stated that no material left the site and that a vacuum truck was used to remove the water/oil for proper treatment/disposal and any impacted soils were removed by a contractor for disposal at Woodside Lanl. |
| 95734 2007-04-28 | Point Source(s): Tank 200-7 exchanger / Tank 450-2 Pollutant(s):#6 Oil, Crude Oil, Diesel - 126 gallons | Cause of Problem: Human Factors a vacuum truck driver loaded the noted mixture from Tank 200-7 exchanger and proceeded to Tank 450-2 to offload. After connecting the discharge line to the tank and pressuring the vacuum truck, the driver realized he had attached the hose to the suctionvalve on the truck rather than the discharge valve. In an attempt to connect to the correct valve, the material released onto the ground and the driver when the cam lock fitting was removed from the vacuum truck discharge line. It was determined that the discharge valve had not been fully seated due to the presence of a small rock | There is no information as to whether this incident was preventable or not. Remedial Measures - the driver was taken to West Jefferson Hospital and treated for nausea and released. Murphy Oil recovered the free liquids with a vacuum truck. Soil with signs of visible contamination has been removed for proper disposal......so what happened to the soil that may have been contaminated but showed no visible signs????? |
| 95731 2007-04-28 | Point Source(s): Heat Exchanger in the Distillate Hydrotreater (DHT) Unit Pollutant(s):Flammable Gas - 431 pounds Hydrogen Sulfide - 53 pounds | Cause of Problem: Other weld failure- release came from a small hole in the side of a heat exchanger in the Distillate Hydrotreater (DHT) Unit. | There is no information as to whether this incident was preventable or not. Remedial Measures -the distillate hydroeater was removed from service and the exchanger was sent off for failure evaluation. The exchanger is scheduled to be repaired and returned to the plant in about 10 days. At that time, the Distillate Hydroeater will be returned to service. |
| 94267 2007-02-28 | Point Source(s): FLARE - HCU Recycle Gas Compressor Pollutant(s):Sulfur Dioxide - 573 pounds | Cause of Problem: Process Upset during a startup event there was a release of sulfur dioxide. There was a shutdown of the #3 Sulfur Recovery Unit on 2/26/2007 due to a malfunction in the HCU Recycle Gas Compressor resulting from a faulty governor on the steam turbine lube oil pump. That caused the automatic safety shutdown of the Hydrocracker. | This incident was not preventable because the failure of the governor was not predictable. Remedial Measures - While the governor is subject to the Preventative Maintenance program, the refinery will assemble a team to investigate possibilities fro improving the reliability of the compressor assembly |
| 94158 2007-02-23 | Point Source(s): FLARE-Temperature Transmitter / Pollutant(s):Sulfur Dioxide - 367 pounds | Cause of Problem: Equipment Failure the startup followed a shutdown of the #3 SRU complex on 2/23/2007, after its source of acid gas, the Hydrocracker Unit, experienced an automatic safety shutdown . The shutdown was triggered by a high temp. indication on the HCU Makeup Gas Compressor. Atemp. transmitter failed due to damage to its insulation and a loose connection. In failing, the transmitter sent a false high temp. indication, which triggered the shutdown of the compresso | This incident was not preventable because the failure of the wiring was not a predictable event. Additionally, the excess emissions are a normal part of the unit startup. Remedial Measures - MOUSA reprogrammed the transmitter to send a low temp. signal on failure, which will avoid a compressor shutdown. MOUSA activated the instrument's dual element technology, such that if one element fails, it will automatically switch to the backup. This will improve the reliability of the transmitter. Nthe shutdown was triggered by a high temp. indication on the HCU Makeup Gas Compressor A. A temp. transmitter failed due to damage to its insulation and a loose connection. In failing, the transmitter sent a false high temp. indication, which trigge |
| 93741 2007-02-05 | Point Source(s): FLARE- Boiler feed water steam turbine pump Pollutant(s):Sulfur Dioxide - 157 pounds | Cause of Problem: Process Upset there was a trip in the boiler feed water steam turbine pump. The backup electric pump auto started as designed but before the water level in the boiler was back to normal, there was an event that released listed amount of S02 from the flare. This is considered to be a process upset | Verbal Report - There is no information as to whether this accident was preventable or not. There is no information regarding any remedial measures that have been taken in regards to this incident. Note: the LDEQ writes this concerning the flare, The flare does operate as designed and at times is noisy and smokey. |
| 93737 2007-02-05 | Point Source(s): Air Products hydrogen plant Pollutant(s):Sulfur Dioxide - 458 pounds | Cause of Problem: Process Upset -The startup followed a shutdown of the # SRU complex on 1/28/2007, after its source of acid gas, the Hydrocracker unit, was shut down. The Hydrocracker unit, which is supplied by Air Products via pipeline. A malfunction of the Air Products hydrogen plant forced MOUSA to shut down the hydrocracker. This incident is a normal startup of a Sulfur Recovery Unit | This incident was not preventable because, excess emissions are a normal part of the unit startup. No human error was involved. Remedial Measures are listed as, the excess emissions are a normal part of the startup. The LDEQ incident report further explains that, The # 3 SRU was being brought on line. The process took about 6 hours. Murphy's written report to LDEQ incorrectly dated 1/12/2007 states that the startup followedhutdown of the #3 SRU complex on 1/28/2007, after a malfunction in at the Air Products Hydrogen Plant forced MOUSA to shut down the Hydrocracker |
| 93421 2007-01-22 | Point Source(s): Underground PVC drain collection system Pollutant(s):Crude Oil - 126 gallons | Cause of Problem: Piping or Tubing The source of the spill was a crack in the underground PVC drain collection system that has since been repaired. | Three barrels of crude oil were released inside the secondary containment area of Tank 250-1. There is no information given as to whether or not this accident was preventable or not. Remedial Measures - A preventative maintenance work order will be created to insure weekly vacuum truck service to pump out the north tank farm sump. Murphy Oil deployed contaminant booms and recovered the free liquids with vacuum trucks. Soil with signs of visual contamination is being removed for proper disposal. |
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