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|LDEQ Accident Number
|Point Source(s)||Notes||Amount of Release|
|Tail gas treatment unit (TGII) at Sulfur Recovery Plant||Cause: Under Investigation|
Notes: Sour H20 Stripper contained hydrocarbons which will foul the SRU. Off site impact of short duration
|Tail gas treatment unit (TGII) at Sulfur Recovery Plant||Cause: No information given|
Notes: DEQ representative goes to site - does fenceline readings after a CITGO reading indicates a reading of 24ppm of Hydrogen Sulfide. 0's across the board
|B-7 Flare 3(IX)33 ; Sulften absorber vent at Sulfur Recovery Unit 3(XX-H)1 ; TGII Absorber Vent at Sulfur Recovery Unit 3(XX-J)5 ; furnaces and boilers ; sweet crude oil pipeline to Tank 101||Cause: short duration rain event; swirling winds 60mph+, hail and lightning - see notes - see not|
Notes: The storm caused a loss of power at Substation 21 and power blips on lines from Entergy impacting the Sulfur Recovery Plant. CITGO believes water entered the Substation via a the joint b/w the roof and the side wall causing a fused switch failure. Loss of power resulted in higher pressure and increase in liquid levels causing flaring at B-7. Loss of amine flow and hydrogen sulfide absorption generated heavy smoking from some of the boiler stacks and upset the Sulfur Recovery Plant. Operations pnnel inadvertently overloaded the Central Amine Unit causing high SO2 emissions throughout the Refinery. The crude oil leak was caused by internal corrosion. Limited offsite impact from soot from smoking boilers. REMEDIAL ACTIONS --> A Root Cau
|Sulften tail gas treatment unit||Cause: See notes|
Notes: Leak in a cross exchanger increased hydrogen sulfide emissions from the absorber vent.
|A-Sulfur Recovery Unit||Cause: analyzer malfunction at the A-Sulfur Recovery Unit|
Notes: off site odor complaint
|Tail gas treatment unit at Sulfur Recovery Plant||Cause: No information given|
Notes: Claims emission was below RQ
|Tail Gas 2 Unit||Cause: "B tower water stripper unit had foaming. This caused the relief valve in the tail gas unit to be picked up by an analyzer. The analyzer goes to alarm. The gases were then figured to release into the air."|
Notes: No information given as to remedial actions. Classified as "a non-emergency" situation
|B-7 Flare EQT347|
Fired heaters and boilers
Sulfen Vent Stack EQT297, Tail Gas II Vent Stack EQT298, B-7 Flare
Sulften Vent Stack, Tail Gas II Vent Stack
|Cause: The operator failed to manually reset the solenoid valve that controlled the level in the F-104 drum prior to restarting the JC-102 compressor. Based on the definition of control equipment inLAC 33:III.1 1 1, Citgo failed, in this incident, to diligently maintain control equipment in proper working order whenever emissions were being made.
That initial failure to reset the solenoid valve cause a string of upsets, which began with the central amine upset.|
Notes: Immediate corrective actions taken were removing excess hydrocarbon from the central amine unit, amine feed to the SRUs was reduced, and efforts were made to identify the hydrocarbon source. Citgo conducted an incident investigation, which outlines several actions to be taken. Additional letters from refinery regarding this incident: 8/18/11, 10/27/11
|Tail Gas II vent||Cause: Citgo Petroleum reported elevated levels of reduced sulfur compounds in the Tail Gas II vent at the Lake Charles Manufacturing Complex, but no information is given about the cause of the release.
In the initial notifications made by phone, Citgo reports that the suspected cause is a leak and that repairs were being made.|
Notes: CITGO's preliminary review of the operating data from this incident indicated that an RQ for H2S may have been exceeded, but CITGO confirms that no RQs were exceeded in a report submitted 1/9/13.