Home Search Emissions Pollutants About the Database


Chalmette Refining (1376), Chalmette

Releases of Hydrogen Sulfide

LDEQ Accident Number
Accident Date
Point Source(s) Notes Amount of Release
84745-84794

2005-12-22
Sulfur Recovery Unit Train 2
Cause: Instrument malfunction caused the automatic shutdown of the refinery sulfur recovery unit train 2, resulting in the routing of refinery acid gas to the flare system (No. 1). Equipment malfunction on SRU 2...leak ongoing...NOX, SO2, H2S. Siting the related incident, ldeq # 84794: According to the refinery, an electrical supply malfunction on the Rich DGA Pump G-8291 caused the automatic shutdown of the refinery Sulfur Recovery Unit Train 2. The shutdown resulted in routing of refinery acid gas to the flare system Loss of one of the amine circulating pumps #g8291 on SRU train 2...NOX, NO2, SO2, H2S

Followup: No

Notes: The following details are for LDEQ incident # 84745, but there is another event (ldeq 84794) which will be discussed in further detail in the 2nd section below: Operations were conducted in order to minimize emissions while maintaining a safe and orderly stabilization of refinery operations and restart of the impacted process unit. Repairs were made to applicable instrumentation and SRU Train 2 was restarted, ending the incident. The refinery has initiated an investigation into the cause of this incident. Based on the result of that investigation, appropriate measures will be taken in order to prevent a recurrence due to the same cause. SO2, H2S, nitric oxide, NO2 released to atmosphere through the refinery number 1 flare and to a lesser extent via the refinery sulfur recovery unit thermal oxidizer stack. Operations were conducted in order to minimize emissions while maintaining a safe and orderly stabilization of refinery operations and restart of the impacted process unit. Repairs were made to applicable instrumentation and SRU Train 2 was restarted, ending the incident. In a separate but related incident report that is linked to the event detailed above (LDEQ # 84794) the following details pertain to that release, but the pollutant totals have been combined: pollutants from incident number 84794 have been combined in the pollutant totals in the table below, but the original report for 84794 had listed these quantities which have all been added to the totals mentioned in report 84745: Hydrogen Sulfide 273.0 pounds Nitric Oxide 239.0 pounds Nitrogen Dioxide 27.0 pounds Sulfur Dioxide 103,560.0 pounds Operations were conducted in order to minimize emissions while maintaining a safe and orderly stabilization of refinery operations and restart of the impacted process unit. Repairs were made to applicable electrical equipment and SRU train 2 was restarted, ending the incident. The refinery has initiated an investigation into the cause of this incident. Based on the result of that investigation, appropriate measures will be taken in order to prevent a recurrence due to the same cause. The Sulfur recovery unit train 1 (SRUTR1) which included the release of 33375 lbs of sulfur dioxide to the atmosphere through the facility's Refinery Sulfur Recovery Unit Thermal Oxidizer Stack. The emissions occurred intermittently from 12/22-25/05 over 35 hour time frame. The unit was shutdown over this timeframe to make necessary repairs. An investigation concluded that a dip-leg of srut1 unit was identified and the unit had to be shutdown. Further investigations revealed that SRUTR1 unit was shutdown prior to katrina and was brought back on line on 12/22/05 when the incident occurred. The shutdown to the SRUT2 resulted in the routing of refinery acid gas to the flare system from 12/22-23/05 for 13.5 hour timeframe. The unit was shutdown over this timeframe to make necessary repairs. Operations were conducted in order to minimize emissions while maintaining a safe and orderly stabilization of refinery operations and restart of the impacted process unit. Repairs were made to applicable electric equipment and SRU Train 2 was restarted, ending the incident. Appropriate measures will be taken in order to prevent a recurrence due to the same cause. These releases of sulfur dioxide exceed reportable quantity. Incident #84745 occurred 12/22 to 12/23 and Incident #84794 occurred from 12/24 to 12/25. The two reports here are also linked to a third report, LDEQ Incident #84723 which is separate on our database.
1,017.0 pounds
No LDEQ Reported

2005-12-18

Coker 2 Wet Gas Compressor K8101
Cause: Compressor went into high alarm for high vibration. It was determined that the vibration probe had provided a false alarm due to a faulty connection. Coker 2 Wet Gas Compressor K8101 went into alarm for high vibration on 12/18/2005.

Followup: No

Notes: This is a letter rescining the notification made relative to Hydrogen Sulfide (H2S). Upon further review, the total amount of H2S is estimated to be less than the reportable quantity (RQ= 100 lbs). Chalmette refinery estimates that approximately 70 lbs of H2S was released to the atmosphere during the 12/18/05 event. In order to avoid equipment damage and associated emissions, refinery personnel shut down the machine in order to evaluate and develop a repair strategy. The vibration probe was repaired and the machine was put back in service, ending the incident. Instrument and electrical connections directly related to K8101 were double checked for proper connections in order to avoid a recurrence due to the same root cause. It was determined that the vibration probe had provided a false alarm due to a faulty connection. The vibration probe was repaired and the machine was put back in service, ending the incident. Instrument and electrical connections directly related to K8101 were double checked for proper connections in order to avoid a recurrence due to the same root cause. Although the facility claims that this was a false alarm, there must have been some type of equipment failure to result in the release of 26,127 lbs of sulfur dioxide. The incident released 26,127 lbs of S02, which exceeds the reportable quantity for S02 (RQ= 500 lbs).
70.0 pounds
84474

2005-12-10

Wet Gas Compressor K8101
Cause: Coker 2 Wet Gas Compressor K8101 shutdown on multiple occasion for uncertain reasons. On December 13, 2005 it was determined that some shutdown relay wiring on K8101 had become less secure than required for consistent operations.

Followup: No

Notes: Chalmette Refinery notified the office regarding a release of Nitric Oxide, Nitrogen Dioxide, Sulfur Dioxide, and Hydrogen Sulfide on December 10,12, and 13. This is a notification by CRLLC rescinding the notification made relative to Hydrogen Sulfide (H2S). Upon further review, the total amount of Hydrogen Sulfide is estimated to be less than the reportable quantity. The RQ for H2S is 100 pounds. Chalmette Refinery estimates that approximately 25 pounds of H2S was released to the atmosphere during the combination of the events. The incident occurred on four separate occasions, during three days. Due to incremental emissions caused by downtime of K8101, the compressor was re-started as quickly as possible during the trips on 12/10 and 12/12. On 12/12, when the compressor once again tripped, the machine was left off-line and refinery instrument and electrical resources were mobilized to conduct more extensive evaluation of the machine before re-start. Coker 2 rates were reduced in order to reduce emissions. It was determined on 12/13/05 that some shutdown relay wiring on K8101 had become less secure than required for consistent operations. The wiring was reinstalled, and the machine was re-started ending the incident. The machine was left off-line until refinery instrument and electrical resources could be mobilized to conduct more extensive evaluation of the machine before re-start. K8101 was repaired in order to minimize recurrence due to the same root cause. Sulfur Dioxide, Nitric Oxide and Nitrogen Dioxide released to atmosphere through the refinery No. 1 flare.
25.0 pounds
84328

2005-12-05
Sulfur Recovery Unit Thermal Oxidizer Stack
Cause: Loss of power triggered upset of refinery and shutdown of the refinery's operating sulfur recovery unit.

Followup: No

Notes: A power outage and refinery shutdown resulted in flaring, including a release of Sulfur Dioxide, Hydrogen Sulfide, Nitric Oxide, and Nitrogen Dioxide beginning 12/5/05 and continuing intermittently during the repair of equipment damaged by the outage. The power outage occurred when Entergy was doing some work at the Meraux substation. The entire refinery lost power. The units are now back on line but at minimal rates while repairs are being performed. The refinery is still flaring S02 and H2S because there was damage to the sulphur plant. Operations were conducted in order to minimize emissions while maintaining a safe and orderly stabilization of refinery operation and restart of some refinery process units. Refinery Management has met with Entergy to stress the impact of this incident and request that appropriate measures be taken in order to prevent a recurrence. Operations were conducted in order to minimize emissions while maintains a safe and orderly stabilization of refinery operations and restart of some refinery process units. This is clearly far exceeding the reportable quantity for sulfur dioxide (RQ=500 lbs).
2,371.0 pounds
84073

2005-11-23
No. 2 Coker Wet Gas Compressor
Cause: The wet gas compressor shut down due to the axial thrust alarm, resulting in emissions from the No. 1 Flare. Following investigation, refinery personnel believe the Wet Gas Compressor shut down due to a momentary loss of lube oil.

Followup: No

Notes: In an effort to stop the release, the compressor was restarted, but the alarm remained. Following determination by refinery personnel that maintenance was required on the compressor, K-8101 was taken out of service and sent out for repair. A variance was applied for with the LDEQ to authorize the emissions associated with the compressor maintenance. The variance was approved on November 29, 2005, ending this release.
685.0 pounds
83924

2005-11-17
Hydrodesulphurization (HDS) Unit Fans
Cause: Leak on the HDS Unit fans caused spill to the ground. Emissions resulted from the spill to the ground, the release to the atmosphere and from the unit de-pressure to the No. 2 flare.

Followup: Yes

Notes: At approximately 04:07 hours on 11/17/05, refinery personnel discovered a leak on the Hydrodesulphurization (HDS) Unit fin-fans. Approximately 9.3 barrels of Distillate range material spilled to the ground. Emissions resulted from the spill to the ground, the release to the atmosphere, and from the unit de-pressure to the no. 2 flare. Chalmette Refinery rescinded the 11/17/05 notifications for NO, NO2, VOC, SO2 and H2S since the estimated amounts were less than the reportable quantity of 10lbs. They estimate that approximately 1.93 and 0.21 pounds of Nitric Oxide (NO) and Nitrogen Dioxide (nO2), respectively, were released to the atmosphere during the 11/17/05 event. Therefore, notification for Nitrous Oxides (NOx) was not required. Calculations performed after the incident indicated that a greater than reportable quantity of oil was spilled to the ground during this incident, and as such, emissions calculations for the oil spill are included in the follow-up report. Hydrogen Sulfide and Compressed Flammable Gas/Non-speciated VOCs released to atmosphere through the leak; Sulfur Dioxide and compressed flammable gas/non-speciated VOCs released to atmosphere through the NO. 2 flare; oil spill to ground with VOC volatilization to atmosphere. The HDS Unit was shutdown and de-pressured to the no. 2 flare to minimize the impact of the leak. A pipe clamp was installed, stopping the leak. Liquid released from the leak was contained and recovered. Soils that appeared to have come in contact with spilled slop oil were removed for off site disposal.
274.0 pounds
81776

2005-08-27

FCC debutanizer overhead condenser
no.1 and no.2 flares
Cause: HURRICANE KATRINA (storm) Release of sulfur dioxide, nitric oxide, nitrogen dioxide, and hydrogen sulfide was due to overpressurization of the FCC debutanizer overhead condenser, resulting in flaring and a small ground fire.

Followup: Yes

Notes: This follow-up letter has been delayed due to Hurricane Katrina. This is a notification that the total refinery shutdown resulted in an evacuation of the refinery and the potential emergency release of wastewater from the wastewater treatment plant outfall. Chalmette Refining conducted a detailed analysis of emissions resulting from the refinery shutdown for Hurricane Ivan in September 204. Since the refinery shutdown for Hurricane Katrina was similar, they have assumed that the quantities released during Katrina shutdown are the same as the Ivan shutdown. Chalmette Refinery is rescinding the 8/27/05 notifications for S02, H2S, NO2, and hydrocarbons (non-speciated VOCs). Upon further review, the facility claims that the total amounts were estimated to be less that the reportable quantities (RQ= 100 lbs). The original estimated quantity of NO was 467 lbs, and was later changed to be estimated at 74 lbs. Shutdown was undertaken in preparation for the forecasted potential for Hurricane conditions. Operations were conducted in order to minimize emissions while maintaining a safe and orderly shutdown. Emissions resulted from gas flaring, fuel gas quality changes, and standby operation modes necessitated by the shutdown. Sometime after Hurricane Katrina, the pilots on the flares were extinguished. By that time, predominantly natural gas was being flared and no reportable quantities were exceeded.The pilots were re-lit on all flares by September 8, 2005 At approximately 12:00 hours on 8/27/05, the FCC debutanizer overhead condenser overpressured due to a failure with a pressure controller, resulting in flaring and a small ground fire. For the FCC, the tower was returned to normal pressure and the pressure transmitter on the overhead condenser was repaired. The small ground fire was extinguished.
64.0 pounds
81795

2005-08-27
FCC Debutanizer Overhead Condenser
Cause: Condenser overpressured due to a failure with the FCC debutanizer overhead condenser, resulting in flaring and a small ground fire.

Followup: No

Notes: For the FCC, the tower was returned to normal pressure and the pressure transmitter on the overhead condenser was repaired. The small ground fire was extinguished. This follow-up letter was delayed due to Hurricane Katrina This is a letter rescinding the 8/27/2005 notification for Sulfur Dioxide (S02), Hydrogen Sulfide (H2S), Nitrogen Dioxide (NO2), and Hydrocarbons (non-speciated VOCs). Upon further review, the total amounts were estimated to be less than reportable quantities. Nitric oxide was released to the atmosphere through the refinery Number 1 flare.
81112

2005-08-08
Sulfur Recovery Unit Pit Blower K8053
Cause: Refinery personnel identified unacceptable levels of SRU vibration in Pit Blower K8053. The blower was shut down for repairs

Followup: No

Notes: Bearing wear was determined to be the cause of the vibration and shutdown of K8053. Repairs were progressed continuously and K8053 was placed back in service.
126.0 pounds
80566

2005-07-16
Hydrodesulphurization (HDS) Unit problem went to No. 2 Flare
Cause: Leak in the HDS due to failure in the piping. Sulfur dioxide released into atmosphere through the refinery Number 2 Flare.

Followup: No

Notes: The unit was shut down so that the leak could be isolated and repaired. Although Chalmette Refinery listed the release of hydrogen sulfide as below reportable quantities, LDEQ's final report states that the minimum reportable quantity was released.
100.0 pounds
80548

2005-07-12
Coker 2, gas then vented to Tank 304
Cause: During tropical storm Cindy there was a power failure. This release happened upon re start.

Followup: No

Notes: The line which allowed the gas to go to the tank was isolated and the incident was ended. The flow indication was calibrated and process logic updated to minimize recurrence. No time given for which the release was stopped, but the event occurred on 07/12/05 at 16:33 hours, was identified at 21:06 hours, and subsequently emission estimates were completed on 07/14/05 at 17:25 hours. No information was given on the amount released of refinery fuel gas in this report.
683.0 pounds
80322

2005-07-06
No information given
Cause: Power failure due to Tropical Storm Cindy, resulting in an unplanned shutdown.

Followup: No

Notes: Due to the multi-day nature of the event CRLLC was unable to give a comprehensive report at this time. As of this report, equipment repairs were still ongoing and addition emissions may occur. Operations were conducted to minimize emissions while maintaining a safe and orderly shutdown.
229.0 pounds
78980

2005-05-11
K3304
Cause: Leak on the Hydrodesulphurization (HDS) Unit Off0gas Compressor K-3304

Followup: No

Notes: Sweet streams (lower Sulfur content) were routed to the flare to minimize sour gas flaring. Process unit output was adjusted in order to minimize the total amount of waste gas being sent to the flare. No mention of pollutant other than Nitric Oxide in official report, but attached Summary of Emissions lists multiple pollutants.
78541

2005-04-26
Sulfur Recovery Unit, Hydrocracker, #2 Coker, #2 Crude
Cause: A loss of power to the Refinery's Boiler Instrumentation System caused the shutdown of the three plant boilers which generate the Refinery's 600 lb. steam. The loss of 600 lb. steam production caused upset conditions at a series of Refinery Process Units including the Sulfur Recovery Unit, Hydrocracker, #2 Coker and #2 Crude

Followup: No

Notes: The refinery has initiated an investigation into the cause of this incident. Based on the result of that investigation, measures will be taken in order to prevent a recurrence due to the same cause. The report's Summary of Emissions also states 692 lbs. of HC, 1131 lbs of CO, and 36 lbs of PM were also released at this time.
203.0 pounds
78361

2005-04-19
K-401 (waste gas compressor number 2)
Cause: Waste gas compressor number 2 (K-401) automatically shut down, automatically diverting waste gas to the flare system.

Followup: No

Notes: Low-Sulfur content streams were routed to the flare to minimize sour gas flaring. Output was adjusted to minimize total amount of waste being sent to the flare. Same language about doing an investigation to understand the underlying cause and prevent future incidents.
3.0 pounds
78348

2005-04-18
No information given
Cause: A broken pipe led to the release

Followup: No

Notes: Below reportable quantities
1.0 pounds
78341

2005-04-17
K-401 (waste gas compressor number 2)
Cause: Waste gas compressor number 2 (K-401) automatically shut down, automatically diverting waste gas to the flare system.

Followup: No

Notes: Low-Sulfur content streams were routed to the flare to minimize sour gas flaring. Output was adjusted to minimize total amount of waste being sent to the flare.
2.0 pounds
78226

2005-04-13
K-401 (waste gas compressor number 2)
Cause: Waste gas compressor number 2 (K-401) automatically shut down, automatically diverting waste gas to the flare system.

Followup: No

Notes: Low-Sulfur content streams were routed to the flare to minimize sour gas flaring. Output was adjusted to minimize total amount of waste being sent to the flare. Letter rescinds report of nitric oxide because below reportable quantity.
6.0 pounds
78042

2005-04-06
K-402 (Refinery waste gas compressor number 3)
Cause: K-402 unexpectedly shut down. Shortly after shutdown, refinery personnel identified the cause of the shutdown as a malfunction of the compressor motor ignition system.

Followup: No

Notes: The compressor motor was repaired and the compressor restarted, ending the incident.
90.0 pounds
77936

2005-03-31
K-400 (Refinery waste gas compressor number 1)
Cause: Refinery waste gas compressor number 1 (K-400) unexpectedly shut down. Refinery waste gas automatically diverted to the flare system.

Followup: No

Notes: Adjustments made to the fuel/air mixture and K-400 restarted.
2.0 pounds
77649

2005-03-16
No information given
Cause: Waste gas compressor number 2 (K-401) automatically shut down due to a high temperature.

Followup: No

Notes: Letter rescinds verbal report because incident was not reportable. No release to atmosphere.
2.0 pounds
77549

2005-03-13
C-2307 (Second Stage High-Pressure Separator) level controller; K-2303 (HCU Second Stage Recycle Compressor)
Cause: During maintenance, the Hydrocracker (HCU) Second Stage High-Pressure Separator (C-2307) level controller was inadvertently left in the manual position. Later, HCU Second Stage Recycle Compressor (K-2303) shut down due to high level in C-2307. Shutdown of K-2303 caused automatic depressurization of C-2307 to the refinery flare system.

Followup: No

Notes: Letter rescinds report of Sulfur Dioxide because below reportable quantity.
77290

2005-03-02
Waste Gas Compressor Number 4 (K-406); Copper tubing connecting C-435 (first stage suction drum) to high-level instrumentation
Cause: Waste gas compressor number 4 (K-406) shut down due to failure of piece of copper tubing connecting C-435 to high-level shutdown instrumentation. When it failed, a false high level reading was recorded, causing automatic safety shutdown system to become engaged.

Followup: No

Notes: Low-Sulfur content streams were routed to the flare to minimize sour gas flaring. Output was adjusted to minimize amount sent to the flare. C-435 was retubed, K-406 was checked and restarted.
17.0 pounds
76869

2005-02-11
No information given
Cause: Power failure caused many of the processes to shut down.

Followup: No

Notes:
1.0 pounds
76795

2005-02-07
Unintended over pressurization of the Hydrocracker Light Ends Plant (HCU LEP) Depropanizer surge drum
Cause: Due to the isolation of the sight glass of the hydrocracker light ends plant depropanizer, the automatic level indication equipment was disabled and false reading was transmitted; this condition caused an unintended over pressurization of the HCU LEP Depropanizer surge drum, which was venter to the refinery flare system (No. 2 flare)

Followup: No

Notes: Refinery personnel evaluated the process operation, identified the source of the problem and made appropriate corrections, ending the incident.
1.0 pounds
76775

2005-02-04
Electrical breaker G-457; Waste gas compressor number 2 (K-401)
Cause: Electrical breaker for G-457 malfunctioned, unexpectedly cutting power to all pumps and fin-fans within the refinery waste gas compressor area. Waste gas compressor number 2 (K-401) shut down as a result of the electrical power outage and refinery waste gas was diverted to safety flare system.

Followup: No

Notes: Low-Sulfur content streams were routed to the flare to minimize sour gas flaring. Output was adjusted to minimize total amount of waste being sent to the flare. Note: the breaker for G-457 had been identified for repair and was supposed to be replaced that week.
11.0 pounds
76355

2005-01-22
K-406 (waste gas compressor number 4)
Cause: Waste gas compressor number 4 (K-406) unexpectedly shut down. Waste gas was automatically diverted to refinery safety flare system.

Followup: No

Notes: Rescinding notification for NO2. The refinery waste gas system and refinery operations were adjusted in order to minimize the amount of waste gas being sent to the flare. Sweet streams were routed to the flare in order to minimize sour gas flaring. K-406 was removed from service on 01/27/05 to complete an evaluation of the machine and perform other maintenance. Additional emissions listed in the Summary of Emissions were not mentioned in the report. This incident is related to incident # 76362.(There are two hand-written incident numbers, T76377 & T76382, on the PDF, but LABB believes they are not related to this event).
12.2 pounds
76362

2005-01-21
Hydrocracker Light Ends Plant Butane Splitter Tower & LEP Depropanizer Tower Bottoms Flow Control Valve 50FC060
Cause: (1) 0600 hrs: Hydrocracker Light Ends Plant (LEP) Butane Splitter Tower began to overpressure because LEP Depropanizer Tower Bottoms Flow Control Valve (50FC060) had failed in the open position, letting propane to exit to the Butane Splitter. (2) 1700 hrs: Butane Splitter again began to overpressure due to the presence of propane. The level indication on the level instrument was detecting a false reading.

Followup: No

Notes: Letter speaks of two incidents on same day at 0600 hrs and 1700 hrs but attached report shows three incidents: (1) 4:05 a.m. lasting 3h 42m; (2) 3:15 p.m. lasting 41m; (3) 4:30 p.m. lasting 1h 25m. Amounts of compounds are only given in totals for all 3incidents. This incident is related to incident # 76355. LDEQ states that it is also related to incident # 76395.
0.1 pounds
76224

2005-01-18
No information given
Number 2 Flare -- Pressure Safety Valve (PSV) on Fuel Drum for Number 10 Boiler
Cause: From the verbal report: False pressure indicator on tower, caused relief value to open and gases to mix.

Followup: No

Notes:
76224

2005-01-18
No information given
Number 2 Flare -- Pressure Safety Valve (PSV) on Fuel Drum for Number 10 Boiler
Cause: From the verbal report: False pressure indicator on tower, caused relief value to open and gases to mix.

Followup: No

Notes:
0.2 pounds
76033

2005-01-06
K-406 (waste gas compressor number 4)
Cause: K-406 unexpectedly shut down and waste gas was automatically diverted to refinery safety flare system.

Followup: No

Notes: Sweet streams (lower Sulfur content) were routed to the flare to minimize sour gas flaring. Process unit output was adjusted in order to minimize the total amount of waste gas being sent to the flare. Shortly after shutdown, personnel re-started K-406 restoring the systems ability to process available refinery waste gas streams, ending the incident.
2.0 pounds
92494

2006-12-08
Number 1 Flare
Cause: heavy oil entered Flare drum and was released as droplets

Followup: No

Notes: #2 Flare was quickly relit and steam controller placed in manual mode to stop the pulsating until the #2 Flare System could be stabilized. Spill cleanup was initiated for the heavy oil ffrom the #1 Flare to the batture and the Mississippi River. Heavy Oil was removed from the #2 Flare Drum.
93.0 pounds
91273

2006-10-10
Thermal Oxidizer and Flare 1 - AE-AOA-05-0109 EPN 46
Cause: Discharges came from THOX and Flare 1. The Amine and Sulfur Recovery Units were upset. It was determined that hydrocarbons contaminated the Diglycolamine (DGAš) and required both units to be taken offline. The upset caused excess emissions from the SRU 1 Thermal Oxidizer (THOX). Sulfer Plant feed was diverted to the refinery safety flare system while the conditions which cause the upset were isloated and remedied. CRLLC reduced the rates of acid gas productin units to minimum and lowered total sufer content of remaining feed, within refinery capability.

Followup: No

Notes: CITIZEN COMPLAINT COINCIDES WITH INCIDENT - all acid gas producing units were cut back to minimum rates. The source of hydrocarbon in the DGA system was isolated and then purged. The refinery has initiated an investigation into the cause of this incident. Based on the result of that investigation, appropriate measures will be take in order to prevent a recurrence dut ot the same cause.
2,917.0 pounds
90319

2006-08-29
No information given
Cause: No information given

Followup: No

Notes: Letter written to rescind notification of 8/29/06
1.0 pounds
90163

2006-08-22
No information given
Cause: first stage recycle finfan leak in HCU

Followup: No

Notes: Letter written to rescind notification of 8/22/06
41.0 pounds
89604

2006-07-31
AE-AOA-05-0109 EPN 46
Cause: loss of instrument air pressure resulting in upset and shutdown of multiple process units within the refinery

Followup: No

Notes: Process adjustments were made to restore refinery instrument air and steam systems. Process units were stabilized, ending the incident.
10.0 pounds
87121

2006-04-11
AE-AOA-05-010,9AE-AOA-05-0109 EPN 46
Cause: contamination in the air system

Followup: No

Notes: updated unit operating procedures to remove potential impurities from the line prior to future use.
86817

2006-02-28
NA
Cause: unanticipated failure cause a leak in instrument piping on a sight glass at the Sour Water Stripper Unit. The unanticipated leak caused the release of stripper overhead gasses to the atmosphere.

Followup: No

Notes: Piping was repaired and unit was returned to service. A review of the Sour Water Stripper Unit condensate flush piping will be conducted.
139.0 pounds
85422

2006-01-26
No information given
Cause: No information given

Followup: No

Notes: Letter written to rescind notification of 1/26/06
19.0 pounds
100395

2007-10-22
Cooling Water Exchanger
Cause: cooling water exchanger leak

Followup: No

Notes: No information given
100358

2007-10-20
Emergency Flare System
Cause: incident occurred during shut down of the Sulfur Recovery Unit train 1 for maintenance. Train 2 also shut down, initiating release.

Followup: No

Notes: Operators restarted Train 2 twice before they were able to route acid gas through Train 2 and out of the Emergency Flare System ending the flaring.
566.0 pounds
100315

2007-10-19
Emergency Flare System
Cause: Train 2 shut down due to low oxygen flow

Followup: No

Notes: Operators restarted Train 2 to end the flaring.
99999

2007-10-05
Emergency Flare System
Cause: power failure.

Followup: No

Notes: CRLLC followed the Loss of Power Emergency Shutdown Procedures for each unit.
99939

2007-09-28
Waste Water Treatment Plant
Cause: Under investigation.

Followup: No

Notes: CRLLC increased ph in tank 1013 in response to detected sulfides in the feed to minimize H2S emissions.
212.0 pounds
99603

2007-09-19
Hydro-cracker HCU Unit First Stage Reactor
Cause: Hydro-cracker HCU Unit First Stage Reactor malfunction

Followup: No

Notes: Letter states that no RQ's were exceeded
99557

2007-09-18
#1 Flare
Cause: Malfunctioning FCC PGC seal oil level controller. I/E was requested. While I/E's were making adj. the compressor shutdown and excess gas was sent to #1 flare.

Followup: No

Notes: Compressor was restarted ending the flaring. The seal oil level control was replaced.
99496

2007-09-16
Cat Feed Hydrotreater Unit
Cause: piping failure due to corrosion from leak of DGA and H2S into piping system from DGA contactor. Drop in reactor pressure on the CFHT unit. Leak on outlet piping of the Fin Fan. Emer. shutdown due internal corrosion from a leak of diglycolame/Hydrogen Sulfide

Followup: No

Notes: Emergency shutdown was initiated. Water spray was applied to decrease emissions until the unit could be safely depressured. CRLLC inspected entire piping system and ID' other corroded areas. CRLLC plans to increase frequency of outlet piping system inspections. DEQ letter of 10/11/07 indicates that incident will be referred to enforcement because it is preventable.
2,334.0 pounds
99117

2007-09-04
#1 Flare
Cause: No information given

Followup: No

Notes: Letter states that no RQ's were exceeded
100575

2007-09-04
#2 Coker Unit
Cause: flare isolation unit on coke drum didn't seal when closed. Opened drum to cut it, flare gas backed into drum to atmosphere.

Followup: No

Notes: No information given
99116

2007-09-03
No information given
Cause: SRU unit, train 1, pit blower K8003 suffered equipment failure.

Followup: No

Notes: Letter states that no RQ's were exceeded
98779

2007-08-20
Flare
Cause: compression fitting on tubing failed on salt water stripper

Followup: No

Notes: No information given
98556

2007-08-10
No information given
Cause: Under investigation. Source is wastewater treatment plant.

Followup: No

Notes: Ongoing intermittent release of H2S. Suspected sources contaminated water are being isolated and a sampling schedule has been implemented for all sources leading to the WWTP Feed Tank 1013. CRLLC is sampling for sulfides and pH every 6 hours on all streams entering the WWTP. Sampling will continue until a source is Id'd.
6,407.0 pounds
98248

2007-07-31
Flare
Cause: No information given

Followup: No

Notes: Letter states that no RQ's were exceeded
98057

2007-07-23
No information given
Cause: see notes. Amine Contactor Tower had flooded

Followup: No

Notes: Root cause under investigation
1,134.0 pounds
95652

2007-04-25
No information given
Cause: No information given

Followup: No

Notes: Letter sent to rescind notification of 4/25 concerning release of SO2, NO, NO2, H2S,
0
93419

2007-01-21
Coker B Drum
Cause: No information given

Followup: No

Notes: Letter sent to rescind notification of 1/21/07 concerning release of VOC and SO2
10.0 pounds
93199

2007-01-10
No information given
Cause: No information given

Followup: No

Notes: Letter sent to rescind notification of 1/10/07 concerning release of H2S
2.0 pounds
93200

2007-01-10
1st Stage Fin Fan E2415 tube
Cause: leak in tube on 1st stage fin fan

Followup: No

Notes: Root cause analysis initiated. Tube has been sent offsite for analysis. Measures will be taken based on result of analysis.
194.0 pounds
93101

2007-01-07
Sulfur Recovery Unit
Cause: the governor control arm was sticking which caused a problem with the blower.

Followup: No

Notes: Initial report indicates emissions were: SO2 - 500 lbs and H2S - 100 lbs, but letter from Chalmette states that further investigation indicates amt released of both substances was 0 lbs. Follow-up letter adjusts emissions to numbers listed here.
8.0 pounds
110720

2008-11-09
No information given
Cause: No information given

Followup: No

Notes: Letter states that emissions were BRQ.
110547

2008-11-01
Catfeed Hydrotreater Unit
Cause: developed a leak on C7715, rich DGA flash drum at nozzle weld

Followup: No

Notes: Letter states that emissions were BRQ.
110493

2008-10-30
Sulfur Recovery unit THOX stack
Cause: lost a burner during start up of THOX

Followup: No

Notes: Letter states that emissions were BRQ.
110391

2008-10-25
#1 Flare
Cause: upset condition in a process unit

Followup: No

Notes: Letter states that emissions were BRQ.
110004

2008-10-10
Once Through Cooling Water System
Cause: heat exchanger leaking

Followup: No

Notes: Letter states that emissions were BRQ.
108944

2008-09-12
Flare #2
Cause: Hurricane Ike causes a scaffold to fall and damage a power line. Power outage causes shut down of Crude 1 and Crude 2 Units

Followup: Yes

Notes:
No information Given

2008-08-30
Flare
Cause: shutting down units due to hurricane

Followup: No

Notes: All incidents grouped in one report concerning activities surrounding start up and shut down near the arrival of Hurricane Gustav. CRLLC reports requesting a variance for all emissions resulting from these events.
1,506.0 pounds
108416

2008-08-28
HDS Unit
Cause: No information given -leak in fin fans

Followup: No

Notes: Claims emission was below RQ.
108408

2008-08-28
Crude Oil Tank
No information given
Cause: No information given

Followup: Yes

Notes: According to letter, calculation of emission amount is pending
108408

2008-08-28
Crude Oil Tank
No information given
Cause: No information given

Followup: Yes

Notes: According to letter, calculation of emission amount is pending
108528

2008-08-20
Flare
Cause: shutting down units due to hurricane

Followup: No

Notes: No Information Given
108060

2008-08-15
number one pump around
Cause: -- piping leak on number one pump around

Followup: No

Notes: Claims emission was below RQ.
107890

2008-08-08
Sour Water line depropanizer feed surge drumlevel controller at the LEP
Cause: leak on the sour water line

Followup: No

Notes: Claims emission was below RQ.
106122

2008-06-03
Train 1 Reaction furnace
Cause: hairline crack in a weld where the side port nozzle enters the Train 1 Reaction furnace. SRU operations were adjusted to minimize emissions from this crack.

Followup: No

Notes: Inspectors analyzed the area of the leak and a repair plan has been initiated. SRU operations were adjusted to minimize emissions.
222.0 pounds
104939

2008-04-20
SRU Train 1 Acid Gas Burner assembly
Cause: internal corrosion from acid gas condensation is suspected to have caused the leak on the underside of the gas burner assembly.

Followup: No

Notes: SRU operator switched the combustion source from oxygen to air to stop the flow of acid gas through the portion of the acid gas burner assembly where the leak occurred. Metallurgy of nozzle will be be reevaluated for service and it is planned that the nozzle will be replaced during the late 2008 turnaround.
116.0 pounds
103126

2008-02-17
Flare
Cause: conducting functionality test for acid evacuation system. On of vent valves opened to flare.

Followup: No

Notes: Letter states that emissions were BRQ.
1.0 pounds
08-BB005-672

2008-02-12
1st Stage High Pressure Separator on the Hydrocracker Unit
Cause: ; thermal stress from start up and shut down, along with cold rain that occurred on the day the leak was detected caused a flange to leak

Followup: No

Notes: CRLLC sends letter to rescind prior notification of H2S release.
102968

2008-02-10
FCC Fractionator Overhead Receiver
Cause: process gases escaped to the atmosphere through the FCC Fractionator because gas in the flare gas header was allowed to reach the overhead receiver due to inadequate isolation between the two systems

Followup: No

Notes: CRLLC immediately closed the valve on the Overhead Receiver and conducted a check of all the remaining valves on the unit to verify that all the valves were closed.
236.0 pounds
120390

2009-12-28
#3 Pretreater overhead accumulator
Cause: #3 Pretreater overhead accumulator had leak on site glass.

Followup: No

Notes: RQ not exceeded.
120342

2009-12-22
flange
Cause: Leaking flange caused release.

Followup: No

Notes: RQ not exceeded. Clamp was placed over the leak.
117792

2009-09-06
tank
Cause: Valve stuck at the top of a tank.

Followup: No

Notes: RQ not exceeded. Repair was performed promptly.
100.0 pounds
116591

2009-07-20
Desulphurization unit clamp
Cause: Desulphurization unit clamp leaked.

Followup: No

Notes: RQ not exceeded.
114850

2009-05-09
HDS unit
Cause: HDS unit leak on outlet of E3301. Shut down to do repairs causing release..

Followup:

Notes: RQ not exceeded.
8.0 pounds
112952

2009-02-23
No Information Given
Cause: No Information Given

Followup: No

Notes: Below reportable quantities.
112467

2009-02-02
No Information Given
Cause: No Information Given

Followup: No

Notes: Below reportable quantities.
57.0 pounds
112269

2009-01-24
#1 Flare
Cause: No Information Given

Followup: No

Notes: Below reportable quantities.
0.4 pounds
112239

2009-01-23
No Information Given
Cause: No Information Given

Followup: No

Notes: Below reportable quantities.
8.0 pounds
112124

2009-01-19
No Information Given
Cause: No Information Given

Followup: No

Notes: No Information Given
31.0 pounds
126868

2010-10-04
saturated gas line to saturated amine contactor
Cause: WORKER DIED 10/6--"cause of death under investigation" "saturated gas line to the saturated amine contractor started leaking sour gas to the atmosphere through a previously installed clamp" which had been installed 9/22/10.

Followup: Yes

Notes: area barricaded off, work stopped & personnel moved to safe area, respiratory protection for workers in immediate vicinity, internal & external monitoring, clamp on leak repaired/isolated, will have to flare intermittently until line can be completely replaced. "No chronic or acute health risks are anticipated to have occurred off-site or beyond immediate proximity of release point."
732.0 pounds
126494

2010-09-20
no information given
Cause: "flammable gas in pipe rack" --no further details/explanations Follow-up notifications on 9/21 and 22 referenced in refinery letter but not included in file.

Followup: No

Notes: "Attempted to identify line...set up safe zone perimeter...safety personnel taking readings" no additional information
126170

2010-09-07
Fin Fans
Cause: LDEQ report states the event released hydrogen sulfide and VOC for 163 minutes. CRLLC had a tube failure on the inlet side of an exchager at the hydrodesulfurization unit. Gas was released into the atmosphere. Follow-up report states that the leak was the result of thermal cycles on the fin fans which occurred during a power interruption. The unit was shutdown and fin fan exchanger was purged with nitrogen.

Followup: Yes

Notes: RQ. Unit was shutdown and exchanger purged with nitrogen. LDEQ report states that DEQ database was checked several times for a 60 day follow-up notification but no report was sent within 60 days. When contacted they stated no knowledge of 60 day notification requirement. The facility then submitted the second follow-up report notification with root cause analysis. According to the report, the event was not preventable. This facility referred to circuit rider for not submitting the second follow-up notification in accordance with LAC 33.I.3925.A.3
383.0 pounds
126163

2010-09-06
FCC regenerator flue gas scrubber vent
FLARE: Flare #1
FLARE: Thox stack, Flare # 1 and 2
Cause: Bus bar short to ground due to unsealed air gaps created a voltage dip which resulted in power loss to multiple units which then had to flare. Pressure imbalance in the FCC regenerator resulted in loss of catalyst through the regenerator flue gas scrubber vent. FLARE.

Followup: Yes

Notes: "To reduce the likelihood of recurrence, sealant was installed between the bus bars and supports in PS 7711 and acoustic inspection is being performed at another power station that was designed and installed by the same contractor." Refinery letter states that "there was no emergency condition related to this release and the resulting community exposures would not be expected to have acute or chronic health impacts."
283.0 pounds
123040

2010-04-27
flare #1
Cause: Compressor inadvertently tripped while executing Emergency Block Valve Prevention Maintenance Program procedure on it--sent material to flare.

Followup: No

Notes: Operations team secured the unit and started up the compressor, full evaluation and troubleshooting will be addressed during next shutdown. Will not perform EBV maintenance program in the meantime.
122546

2010-04-03
no information given
Cause: "Unloading olefin truck--vent line to flare left open"--no details.

Followup: No

Notes: no information given
134471

2011-10-10
FLARE-No. 1 Flare; SRU 1
Cause: There was sudden unexpected loss of O2 supply from Air Products causing SRU1 to immediately shut down. Acid gas (SO2 and H2S) was released intermittently through Number 1 Flare. SRU 1 was sole operating SRU at the time of incident, as SRU 2 was shutdown for maintenance.

Followup: No

Notes: Steam controllers have been repaired and rebuilt. There was also an evaluation of alarm changes to provide more response time. EPA Acid Gas Flaring report included. LDEQ conducted an investigation in response to this incident on 12/8/11.
595.0 pounds
133880

2011-09-11
FLARE: Flare No. 1
Cause: A packing leak developed on the seal of the fire eye cleaning device causing it to malfunction during routine maintenance and allowed combustion gases to escape to the atmosphere and shutting down Train 1 of the SRU (Sulfur Recovery Unit) sending acid gases to the FGM. Flared from flare 1 at a reportable quantity of H2S/SO2.

Followup: No

Notes: Unit operations were adjusted to minimize the duration and severity of flaring. The SRU Train 1 was switched to oxygen mode so it could process refinery acid gas. Sulfur pit vents on both trains were opened until SRU 1 could process them. To prevcnt this from happening again a re-engineered fire-eye cleaning tool will be constructed. This is expected to be completed by December 31, 2011. CRLLC will not utilize the fire-eye cleaning tool until modification to the tool has been completed. Two employees received first aid treatment. No chronic or acute health risks are anticipated as a result of this release. There was no emergency condition as a result of this release. NO SPOC or LDEQ report.
220.0 pounds
132776

2011-07-29
Flare 1
Cause: On 01/28/11, at approximately 9:00am, the amine unit was being taken out of service for a planned maintenance activity. During the course of the shutdown, the DGA circulation in the contactor decreased. The reduced flow occurred concurrent with the loss of the LPG compressor. As a result, there was an H2S breakthrough to the refinery fuel gas system at approximately 1 minute. This event resulted in 86 lbs of excess SO2 emissions.

Followup: No

Notes: Fuel Gas incident- The shift leader recognized the problem within 15 minutes of the start of the event and immediately increased circulation to stop the H2S breakthrough and mitigate the SO2 emissions potential. Updated procedures to ensure shutdown activities include awareness of circulation rate and interaction with other unit operators. Refresher training will be conducted with unit personnel on revised procedure. In a separate event at 12:58am, the flare gas management compressors briefly shutdown due to elevated molecular weight (MW) gas which resulted in increased SO2 emissions from the fired combustion units of 481 lbs excess SO2
132721

2011-07-23
Flare
Cause: On July 23, 2011 at approcimately 23:33 hours, a safety valve on the propane/polypropylene mix drum, D9007 relieved to the No. 1 Flare, resulting in intermittent flaring, and consequently resulting in emission of sulfur dioxide in excess of the reportable quantity of 500 lbs. Incident 11-04337 occurring on July 21, 2011 caused a buildup of hydrocarbons in the compressor seal water decreasing the capacity of the compressors which normally have the capacity to contain this volume.

Followup: No

Notes: The seal water on the FRM compressors was changed out as the hydrocarbon buildup contributed to the flaring. Pressure build up in the spheres occurred before the seal water could be changed out in the compressors causing intermittent flaring. The venting could not be delayed as it would have been a process safety issue. Flaring does not normally occur from these procedures.
131805

2011-06-13
fin fan on the Cat Feed Hydrotreater
Cause: Aire release of hydrogen sulfide and compressed flammable gas from fin fan on Cat Feed Hydrotreater at Chalmette Refining. According to the refinery letter, "the Cat Feed Hydrotreater (CFHT)Unit lost power during a transformer switch, resulting in a pressure increase, and the subsequent leak on the E-7778 fin fan." It was determined that the cause was premature corrosion in the overhead fin fans of the CFHT Unit.

Followup: No

Notes: RQ of hydrogen sulfide. BRQ of VOCs. Inventory was removed from the unit and system pressure was reduced in order to stop the leak and make necessary repairs Chalmette Refining retained U.S. Risk Management to perform community monitoring during the event. The fin fan tube was isolated until repairs and/or replacement are completed.
111.3 pounds
131070

2011-05-09
PGC 2nd Stage Aftercooler
Cause: The PGC 2nd Stage Aftercooler leaked hydrocarbon vapors and compressed flammable gas was released to water. OFFSITE IMPACT: Mississippi River.

Followup: No

Notes: BRQ. Refinery letter states that release was below reportable quantities. The exchanger was isolated and the path to water was closed. A boom was deployed at the source and downriver.
130822

2011-04-26
Fractionator Overhead Fin Fan
Cause: LDEQ states that a leak was observed in the Fractionator Overhead Fin Fan at the Cat Feed Hydrotreater, releasing compressed flammable gas and hydrogen sulfide.

Followup: No

Notes: RQ. Unit commenced an orderly and safe shutdown in order to stop the leak and make necessary repairs.
304.0 pounds
No LDEQ Reported

2012-10-10
no information given
Cause:

Followup: No

Notes: Preliminary air monitoring was observed.
142422-142489-143217

2012-08-27
Coke Conveyor Facilities
flare
isolated areas of standing stormwater
Wastewater treatment Unit
Cause: Chalmette Refining LLC shut down operations because of the approach of Hurricane Isaac. Following established shutdown procedures and protocols, CRLLC was safely and systematically shutdown due to the approach of Hurricane Isaac. Likewise, CRLLC followed standard startup procedures and protocols and minimized excess emissions during recovery and startup efforts.

Followup: Yes

Notes: There are three LDEQ incident numbers assigned for the events at Chalmette Refining LLC surrounding Hurricane Isaac: 142422, 142489, 143217. On August 27, 2012 the CRLLC began to safely shut down unit operations due to Hurricane Isaac. The emergency shut down resulted in potential permit deviations and reportable quantity exceedances. However CRLLC believes that this event qualifies as an upset as defined in LAC 33:III.507.J. Below are the detailed quantities released from each unit during the startup/shutdown activities: Acid Gas and Hydrocarbon Flaring: During the shutdown and equipment preparation, excess process gases were vented to the flare system in order to reduce emissions to the atmosphere. The duration of flaring was approximately 21.1 hours. Below are the emissions which occurred during shutdown activities: 23.6 Tons S02 126 lbs H2S 133 lbs NO 133 lbs N02 714 lbs CO 558 lbs VOC 72 lbs PM10 On August 31, 2012, CRLLC began start-up operations and equipment preparation which required periodic hydrocarbon flaring. There were temporary visible emissions of smoke from flaring activities. Further, during startup of the SRU, there was a transient period which resulted in flaring amine acid gas prior to directing to the SRU. Below are the estimated emissions during startup of refinery operations. The duration of the amine acid gas flaring was 89 minutes and the duration of the intermittent hydrocarbon flaring during startup was 84 hours. Actual emissions were: 10.03 Tons S02 (> 500 lbs RQ) 0.03 Tons H2S (> 100 lbs RQ) 0.28 Tons NO/N02 (> 1000 lbs RQ) 1.52 Tons CO 0.69 Tons VOC (>5000 lbs RQ) 0.08 Tons PM10 <1 00 lbs Benzene (> 10 lbs RQ) There were approximately 9 hours where the H2S 162 ppm 3-hour rolling flare limitation was exceeded during shutdown and startup activities. These excess emissions are covered under startup/shutdown provisions provided in NSR CD Paragraph 58. As such, no additional action is required by agency. Flare Gas Recovery equipment was being repaired and so no FGR was used during this process. Tail Gas Incident: On August 27, 2012 the CRLLC Sulfur Recovery Unit was safely shut down and equipment was prepared. During this process Tail Gas Incident resulted from Source ID EIQ193. Predicted emission estimates were approximately 25 tons S02 for the shutdown. On September 5-6, 2012 the Sulfur Recovery Unit was started-up. There were no tail gas incidents during this process. As such, no additional action is required by agency. Sulfur Pit Venting: Emission estimates were expected to be less than 200 pounds H2S during shutdown and start-up operations. It is important to note that these exceedances occurred during the period when CRLLC was shutting down equipment and subsequently starting up and lining out operations. Actual emissions were -72 lbs. H2S and -50 lbs. S02. These excess emissions are covered under startup/shutdown provisions provided in NSR CD Paragraph 58. As such, no additional action is required by agency. H2S Concentration of 162 ppm in Fuel Gas: During shutdown on August 27, 2012 the refinery had the potential to exceed the H2S concentration of 162 ppm in the fuel gas system. FCCU NOx, S02, CO, PM, and Opacity Permitted Emission Limits: During shutdown and subsequent start-up operations, the refinery exceeded the emission concentration limit for CO for 14 hours and the differential pressure parameter for 32 hours at the FCCU. There were no Title V permit limit lb/hr exceedences during these times. SRU Permitted Emission Limits (lbs/hr & concentration): During the shutdown and subsequent start-up operations, the refinery exceeded the permitted emission limit of 95 lbs/hr for S02 for three (3) hours at the Sulfur Recovery Unit. The 250 ppm concentration limit was exceeded for approximately 48 hours. It is important to note that these exceedances occurred during the period when CRLLC was starting up and lining out operations. These excess emissions are covered under the start-up/shutdown provisions provided in NSR CD Paragraph 23 and 29. Flare Pilot Outages: During the shutdown due to the higher than normal rain and wind volumes, flare pilots experienced temporary outages. Data Availability from Continuous Emission Monitoring Systems (CEMS): The CEMS analyzers at the CRLLC may be adversely affected by nitrogen constraints. Some selected CEMS may have reduced data availability during the time period of storm landfall, recovery, and start-up activities. The specific duration of reduced data availability will be provided in the 30- day follow-up report. Missing LDAR Monitoring: CRLLC is subject to several Louisiana & Federal Regulations requiring Leak Detection and Repair (LDAR) as noted below. Hurricane Isaac and its aftermath have not allowed completion of some of the timing obligations, and will prevent us from meeting all the timing obligations of the required August monitoring. Approximately 250 components will receive delayed monitoring, but will be monitored in September. Details of the number of components subject to delay will be provided in the 30-day follow-up report. Consistent with USEPA's decision for Hurricane Gustav, CRLLC requests that the delayed monitoring and repair be exempted from enforcement under the applicable Force Majeure provisions. Approximately 255 monthly LDAR components received delayed monitoring, but were monitored in September. In addition, 7 leaks that missed the 5 day attempt and 6 leaks that missed the 15 day attempt due to Hurricane Isaac. Isolated Areas of Standing Stormwater: There were isolated pockets of stormwater in the refinery which contained some sheen material and potential hydrocarbon. All of these areas were contained within the refinery boundaries and no material migrated offsite. Areas include tank firewall areas, overflow of sumps, and low-lying areas. There is the potential to exceed more than one (1) barrel of total oil accumulative across the complex from all the isolated areas. All hydrocarbon and sheen material was removed and properly disposed/treated. Any contaminated soil has been remediated. This information is reported in accordance with the site waste management plan. Coke Conveyor Facilities: The coke conveyor facilities sustained some minor damage which resulted in loss of covers over portions of the conveyor belt system. There are also minor amounts of coke material on the ground which is being collected. Some small particulate emissions may result from recovery and re-start Operations. Covers will be repaired/replaced as soon as possible. The 30-day follow-up report will describe the specific repairs and dates of completion. The conveyor covers that were damaged during the hurricane have been repaired/replaced. This accident is linked to Bypass of Wastewater Treatment Unit (LSP incident # 12-05781; NRC Incident # 102-2486). Actual storm rainfall was 30". In consideration of personnel safety and increasing weather severity, the refinery initiated the emergency discharge bypass for Outfall 004 from wastewater treatment facilities to MS River on August 28, 2012. It is important to note that the refinery process operations were shutdown previously which mitigated wastewater hydrocarbon content. Water discharge was essentially storm water. Samples were collected to document wastewater quality. On August 29, 2012 all parameters were within current permit limits with the exception of Total Suspended Solids. Preliminary analysis indicates a potential exceedance of 4,444 lbs/day versus permitted limit of 3,180 lbs.
258.0 pounds
140083

2012-05-26

Cause: The facility experienced malfunctions when the high pressure waste gas system was shut down in the Coker unit, releasing sulfur dioxide to the flare. High Pressure Waste Gas System (HPWGS) compressors K402 and K406 were unavailable due to mechanical issues and the Flare Gas Management System was used instead. This usually works but the depropanizer surge drum water boot sprung a leak and heavy material entered the shut down HPWGS.

Followup: No

Notes: The high pressure waste gas system had been restored by the time of the LDEQ Incident Report.
100.0 pounds
138541

2012-04-03
#1 Flare
Cause: A high molecular weight gas was routed to the flare gas management system, which prevented the compressor from being able to pump the gas and caused the flare to open.

Followup: Yes

Notes: To stop the discharge, feed rate to the unit was reduced, reducing pressure, and eventually ending the release. A representative from Chalmette Refining contacted LDEQ Emergency Response on 4/4/12 when an all-clear was called, also providing the total release quantity of sulfur dioxide. No fire, injuries, or fatalities resulted from this incident
152220

2013-11-07
No Information Given
Cause: Reported release of volatile organic compounds and hydrogen sulfide that occurred on November 7, 2013. No reportable quantities were exceeded during this event.

Followup: No

Notes:
148142

2013-04-16
NIG
Cause: On April 16, 2013 Chalmette Refining experienced a leak of hydrogen sulfide and sulfur dioxide. The refinery letter stated that no reportable quantities were exceeded. No additional information was provided.

Followup: No

Notes:
147793

2013-04-03
discharge pipe from the Flare 1 knockout drum
Cause: On Wednesday, April 3, 2013 at approximately 0145, a Chalmette Refining, L.L.C. (CRLLC) operator noticed odors around the waste water treatment plant (WWTP) shelter. At 0225, CRLLC was notified by St. Bernard Parish Sheriff's Office of a community complaint regarding a potential odor. The potential odor issue was communicated to relevant supervisors during the 0400 shift change, and operators continued to investigate the cause of odor during initial rounds. At approximately 0600, CRLLC personnel detected and reported potential odors, and intensified the investigation to identify the source and possible root cause. Personnel identified a leak from a pipe near Tank 5502 at 0645 and positively identified the source as a discharge pipe from the Flare 1 knockout drum at 0708. Moderate to heavy rain water and insulation covering the pipe, made it difficult to identify the leak source. The root cause of failure was determined to be highly localized internal pipe corrosion.

Followup: Yes

Notes: The pipe section with the leak was completely isolated at 0745, then vacuum trucks were utilized to clean up the spilled material. An engineered pipe clamp was installed to eliminate the pipe leak. To minimize any further potential community impacts from the odor, firefighting foam and suppressants were applied to the area possibly affected by the leak. Contaminated soil was remediated. In addition to determining root cause and actions regarding the pipe failure CRLCC has identified two actions to be taken to improve odor management and response: 1. Update guidelines for addressing community odor complaints. 2. Refresh personnel involved in this incident on expectations for documenting odor complaint activities/ observations on written shift change reports. The accident did result in offsite impact because ExxonMobil officials released this claims number for any community members affected: 866-752-6339. The facility made a small mention of the bad smell that permeated throughout the metro area in their letter to LDEQ. According to Exxon's April 10th report, "While there was no impact to ambient air quality standards set by the LDEQ and EPA to protect health and environment, the leak was malodorous given the 245 parts per million mercaptan levels of the sulfur compounds. While there was no impact to ambient air quality standards set by the LDEQ and EPA to protect health and the environment, the leak was malodorous given the 245 parts per million mercaptan levels of the sulfur compounds. The May 30th follow up updates this value to 127 parts per million. According to the 30 day follow up on May 30, 2013: On July 9, 2013 - CRLLC has pledged to participate in the Jefferson Parish LEPC meeting.
4.2 pounds
147393

2013-03-17
piping
Cause: Due to a crack on a pipeline compressed gas and hydrogen sulfide were released to the air. According to a letter submitted by Chalmette Refining, this was a courtesy notification.

Followup:

Notes:
146246

2013-01-29
no information given
Cause: A release of Hydrogen Sulfide and compressed flammable gas on January 29, 2013. No information given to the root cause.

Followup: No

Notes: According to the facility's report, there were no adverse environmental impacts that occurred during this time.
156620

2014-06-09
Emergency Block Valve at the Crude #2 unit
Cause: A spill of crude vacuum tower bottoms occurred at the Crude #2 unit. While preparing the vacuum tower bottoms (VTB) pump for maintenance, the emergency block valve (EBV) inadvertently opened, releasing crude VTB through the flange opening on the pump. CRLLC is conducting an investigation to determine the cause of the EBV opening and measures to prevent recurrence.

Followup: Yes

Notes: The issue was resolved by isolating the EBV.
153414

2014-01-17

Coker 2 Unit
Cause: On January 17, 2014, there was a release of SO2 to air due to a unit shut down. Chalmette Refining reported that Coker 2 unit shut down causing a flare event.

Followup: No

Notes: According the refinery letter, it was determined that no reportable quantities were exceeded during the event. Prior to the refinery letter, it was estimated that 500 lbs of SO2 was emitted in the SPOC report. Note: A Citizen Complaint (#153347) cites this event as a contributing factor for 3 days of odor, which the citizen described as "terrible."