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Phillips 66 (2418), Belle Chasse

Releases of Volatile Organic Compounds (VOCs)

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

2005-02-28
Saturated Gas plant 7991 -V-1
Cause: The signal to the 7991-V-1 straight run Debutinizer Bottoms level controller stopped transmitting it's signal from the field of the distributed control system

Followup: No information given

Notes: After inspection a set of wires appeared to be frayed. They sent a group of employees to fix the frayed wires.
16,789.1 pounds
92941

2006-12-31
Saturated Gas Plant 7991-V-2
Cause: Failure of the Process Safety Valve

Followup: No

Notes: Could not have been predicted, preventative safety measures were in place already.
5,019.0 pounds
96490

2007-05-23
410-PSV-62
Carbon Monoxide Bypass Stack
Induction gas relief valve (APC-105), Low Pressure Flare, High Pressure Flare
Low Pressure Flare (308F-D-1), High Pressure Flare, 191 APC-105
Low Pressure Flare, High Pressure Flare, 191-PV-105
Low Pressure Flare, High Pressure Flare, SRU incinerator Stack, 191-PV-105, Heaters
Cause: During a rain storm the line from Entergy's substation tripped. The loss of power forced most of the refinery's process units to shutdown resulting in flaring. While shutting down the 191 crude unit the pressure controller relieved vapors and liquid hydrocarbons from a vent at the top of the Vacuum Tower. The hydrocarbons ignited and caused a fire at the top of the Vacuum Tower. With most of the process units down there was insufficient feed to keep the SRU tail gas treater online. The tail gas was routed to the SRU incinerator. When units were started up again they required more flaring for prepare for recommissioning.

Followup: No

Notes: Determined that although there are back up systems there are no ways to prepare for these types of power outages. Electrical department will preform preventative maintenance and replacement of components. 191-PV-105 pressure controller at the crude unit no longer vents to the atmosphere. Piping was installed that routes gases from this vent directly to the flare.
49,498.0 pounds
126678

2010-09-24
308F-D-1 (low pressure flare) and various process heaters
Cause: During maintenance activities, "amine stripper vessel experienced unexpected level swings" and "SRU (sulfur recovery unit) waste heat boiler unexpectedly tripped offline due to its flame scanner no longer detecting a flame at the burner. Several attempts that were made to re-light the burner were unsuccessful due to igniter malfunction" -- had to flare excess.

Followup: No

Notes: "Routed acid gas feed stream to the LP flare and immediately implemented the sulfur shedding plan...root cause investigation has been initiated." Detailed refinery letter only in this file. No LDEQ Report.
70.0 pounds
125632

2010-08-13
Alkylation Unit Isobutane recycle line
Cause: LDEQ report states, "Isobutane leak. There is a pinhole leak in the alkyl unit. The leak could only be seen after temperatures dropped and condensate was visible." Incident report states, "preliminary inspection found that the leak had occurred in a weld on the recycle line. Because the weld failure mechanism is unknown and would require further metallurgical testing."

Followup: No

Notes: Incident report states, "it was decided that the entire Isobutane recycle line shall be replaced with new pipe before starting up the Alkylation Unit."
314.8 pounds
124024

2010-06-07
Butane Divert Line
Cause: A pinhole leak was discovered on the 6 inch elbow of the Alkylation Unit's butane divert line.

Followup: No

Notes: BRQ. A water spray was applied to the leak. Nitrogen was routed into the out of service station of piping to clear the process hydrocarbon out of the leaking section of piping and prevent any further process hydrocarbons from leaking out. A clamp was installed afterwards, once nitrogen became the only chemical being released from the leak. Air monitoring was performed throughout the event, and the clamp was monitored to ensure that nothing was leaking.
580.0 pounds
152230

2013-11-08

Cause: The affected soil was identified through soil sampling beneath tank T-106, which was conducted to assess odors in the work area when the tank was elevated for maintenance. Upon sampling and analysis, it was determined that VOCs and Total Petroleum Hydrocarbons-Gasoline Range Organics (TPH-GRO) exceeded the RECAP Soil_SSi and Soil_ssgw. No soil staining, free phase material, or sheen was observed beneath the tank. The tank resides atop a clay lined foundation and ring structure which isolates the tank bottom from the surrounding soil and ground water. No removal was completed as integrity of the ring structure and cribbing could be compromised by adjacent soil removal.

Followup: No

Notes: The site was investigated on 11/13/13 and odors were detected while lifting Tank 106. Samples of soil varying from 0-12 inches came back with levels of PPHGRO and Benzene above RECAP. Report does not mention specific quantities. On a follow up date sampling at 3 ft was conducted and nothing above RECAP was detected. No sheen or signs of league in or around the tank was observed. No removal was completed as integrity of the ring structure and cribbing could be compromised by adjacent soil removal. A work plan for Tank 106 soil and ground water assessment has been submitted to Remediation Services, dated 12/23/2013 and is viewable in EDMS.