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Confidential
Deer Park Chemical February 28, 2007 Propane Release Incident Cause and Incident Response Review
AGENDA
The incident - what happened
Why did it happen
What did we learn
Recovery measures review
Investigation Approach Bow-Tie
HAZARD
CONSEQUENCE
TopEventLoss of
ContainmentTHREAT
THREAT
THREAT
CONTROLS RECOVERYMEASURES
HazardPotential Consequences
DPCP chose to charter two investigations to understand both sides of the Bow Tie:
– Causes of the Release: What caused or allowed the release to occur?
– Recovery Measures: What gaps in recovery measures occurred?
Incident Description
V1384
February 28th 2007, a 2” carbon steel vertical spool (the “pup”) on the level bridle system below one of the IPA LPG bullets ruptured, releasing ~200,000 lbs of propane to the atmosphere.
V1385 V1384 V1383
TO FLARE
LPG Storage
LGLG
LPG Supply
from IPA
LPG to Refinery & IPA Reactor
Why did this happen?
Pup thinned below pressure retaining
capability
Water wasIn the pup
Fat acid wasin the pup
The pup remained in service until it was below the
pressure retaining capability
The corrosion rate in the pup increased significantly
(accelerated corrosion)
The pup was a dead leg
•The incident was caused by accelerated corrosion due to the presence of weak sulfuric acid in a carbon steel dead leg.•The weak acid was formed by mixing water and fat acid in the pup
Why was water in the pup?
During an IPA LPG Unit shutdown, which occurred in December 2006, water was sent from the IPA LPG unit to the LPG storage bullets (V1383/4/5).
LPG Storage
Fat Acid
T41/42C49 C50 C3086 C3087
De-
Pro
pani
zer
caus
tic/w
ater
was
h co
lum
n
resi
dual
col
umn
V1385 V1384 V1383
To IPA Reactor
LG
To Refinery
Dry Gas
De-
Eth
aniz
er
LG
LPG to storage
Why?•C50 water washed during unplanned LPG Unit shutdown and the LPG unit remained lined up to LPG storage•Water accumulated (inlet valve open & outlet closed) for 3 shifts•Upon detection LPG unit & storage drained•Unable to fully drain pup or check for water, due to configuration •Thus water remained undetected in pup
Why was acid in the pup?
Acid back flowed in to LPG Storage via the C49 Feed Pump Seal flush system due to a combination of a failed check valve and sufficient differential pressure.
Fat Acid
LPG Storage
T41/42C49 C50 C3086 C3087
De-
Eth
aniz
er
De-
Pro
pani
zer
caus
tic/w
ater
was
h co
lum
n
resi
dual
col
umn
V1385 V1384 V1383
To IPA Reactor
LG LG
To Refinery
Dry Gas
T41/42
LG LG
Why?•Fat acid is always in the LPG Unit feed tank (T42)•A seal flush connected T42 to C3087 and the check valve in the seal flush line failed•At times (operating and during partial shutdowns) the pressure at the seal was greater than the C3087 pressure•Seal flush isolation was not called for during shutdowns
Seal Flush
C49 Feed Pump
Failed Check Valve
Why did the pup remain in service?
The pup remained in service until it was below the pressure retaining capability
Why? The accelerated corrosion rate in the pup was unknown, as the presence of weak acid in the
pup was unknown.
Why? Operations believed that all water had been removed from the pup The Production team were unaware of the consequence of having the wrong material in
the wrong location, in this instance fat acid and water at C3087Why?
• Carbon steel is used in fat acid service throughout the unit• PEI were not made aware of the situation
The Production team were unaware of the magnitude of the seal flush backflow issueWhy?
• Individual members of the production team had critical pieces of information, the the problem was not recognized in its entirety.
• All back flow incidents were not recognized
Some Failed Barriers
Mechanical Integrity and Design
Seal flush – connected acid to propane system. Backflow scenario and consequences not pre-identified. Inability to drain LPG bullets of water.
Procedures
Shutdown isolation philosophy. No work instruction for C50 water wash.
People
Unclear ESP Monitoring requirements during shutdown. Inter and Intra department communication. Wrong fluid in the wrong place protocol.
Th
reat
s
Which Barriers Failed?Which Barriers Failed?PeopleProcedures
Mechanical Integrity & Design
Prevention
Propane Release
Mechanical Integrity & Design
Procedures
People
• GAME ESP
• GAME IPF
• GAME EI
• CUI program
• Manage for Reliability
• Advanced process control
• Containment Upgrade USA
• HEMP
• RHA
• Procedure Compliance
• Permit to work
• Contractor HSSE oversight
• HSSE Blitz
• Global Process Standards
• Management of Change
• SWAT
• Focused craft and operator training
• Front line leader development
• Simulators
• Technical & HSSE competencies
• Causal learning
• Seal Flush - connected acid to propane system
• Backflow scenario and consequence not pre-identified
• Inability to drain LPG bullets of water
• Shutdown Isolation philosophy
• No work instruction for C50 water wash
• Unclear ESP Monitoring requirements during shutdown
• Inter and Intra department communication
• Wrong fluid n the wrong place protocol
Specific Learnings
Risk Recognition and Assessment
Potential for process backflow into a finished process system through a seal flush line was not recognized during installation and subsequent risk assessments.
Situations that occurred during shutdowns were key to causing this incident, but risk assessment activities focused on steady state operations.
Multiple conditions had to co-exist for the process backflow to occur, and risk assessment processes included only single jeopardy.
Isolation approach for shutdown allowed valve configuration flexibility that increased risk of unintended material flow.
Specific Learnings
Communications and Abnormal Situation Management
A generally sequential process of communications limited the intra- and inter-departmental interaction, limiting the interpretation and assessment of abnormal situations.
Adaptation to some initially abnormal situations and changes supported deferral of action (such as repair during pit stop).
Unit Monitoring and Response
The approach to high level surveillance, alarm interpretation and response is different during shutdowns than for normal operations.
Training, Procedures, and Work Instructions
Relying on knowledge and experience for execution of what is viewed as routine activities did not support consistent and reliable decisions, especially for newer operators.
Recovery Investigation
High-Level Timeline of Events
0500 – Approximate start time of leak 0510 – OXY identifies leak 0520 – OXY notifies Shell Operations of leak 0530 – Shell Operations calls Security to report site-wide 0600 – ER requests FW Pump #13 to be turned on 0630 – OXY vehicle observed driving into area 0700 – PTRA train travels through plant 0800 – ER isolates leak to 1 vessel (from 3 interconnected) 0830 – ER close leaking vessel isolation valve 0900 – Leak converts from liquid to gas 1000 – Leaking pipe breaks off completely... air-gapped 1300 – Leak isolated and stopped... all clear on site-wide
LPG Bowtie
Security Notification
LOCLeak
Detection
LPG Deluge ER Team & Equipment
ER Notification
Leak Isolation
Material Storage
Ignition Control
De-inventory
Undesired C
onsequences(A
ctual & P
otential)
Operator Response
Recovery Measures – Key Discoveries & Actions
Leak Detection: Observation: Leak detected by Oxy during operator shift change Action: Fixed leak detection is being considered across the site
Security Notification: Observation: Oxy reported leak to Shell operations Action: Re-communicate Shell’s incident notification protocols
LPG Deluge: Observation: Oxy activated deluge for their 3 spheres and firewater
pressure was low for LPG area Action: Validate firewater system is designed appropriately and re-establish
operator firefighting and equipment training
Observation: Deluge testing and emergency activation procedures did not align with dual-valve system
Action: Update deluge testing and emergency activation procedures to:– Validate dual valve systems are tested independently AND– Ensure all deluge valves are opened during an emergency
Recovery Measures - Discoveries
ER Team & Equipment: Observation: Process for site evacuation, or entry in this incident, was unclear Action: Conduct additional training on site evacuation process
NOTE: There were various observations and actions related to ER and Security that came from critiques of this incident, but are not in this report-out
Leak Isolation: Observation: Hazardous accessibility and leaking isolation valve contributed
to time and quantity of material released Action: Remote isolation for certain valves is being considered across the site
Material Storage: Observation: Three propane vessels were interconnected and twelve bullets
were in close proximity Action: Evaluate pressurized C3 and C4 storage vessels for potential
reduction of inventory and connectivity
Recovery Measures - Actions
Ignition Control: Observation: Vehicle drove into affected area Action: Re-communicate vehicle control policy to all employees
Observation: PTRA train proceeded through the affected area Action: Work with PTRA to understand the root causes of the incident
and develop/enhance controls to prevent future occurrences
Observation: Diesel firewater pump in the affected area was activated Action: Initiate project to ensure firewater pump in that area is
intrinsically safe
Backup information
Process Overview
T41/42Feed
C49 C50 C3086 C3087
M
CP3012CP304
Feed pumps
V3086
M
REFLUX
C3 C3
DPS, PHSIPE, C3H2SO4 IPE
C3H20
C3DPSPHS
H2SO4
V3088
Dry Gas
FV3001
FI
SEAL FLUSH
To LPG storage
V1385 V1384 V1383
M
M
To REFINERY
To IPA Reactor
min flow
TO FLARE
CP1391/92
From IPARX 3rd StagePhase Sep
E3
09
0
300 to250psi
250psi
De-
Eth
aniz
er
De-
Pro
pani
zer
caus
tic/w
ater
was
h co
lum
n
resi
dual
col
umn
LPG Storage
Fat Acid
C3
PC PC
LG LG
Water Cause Tree Overview
Water was in the pup
LPG unit was lined up to LPG storage
During an IPA LPG Unit shutdown, which occurred in December 2006, water was sent from the IPA LPG unit to the LPG storage bullets (V1383/4/5).
Water was left in the LPG bullets and the
pup
Water accumulation – inlet valves open-outlet valve closed
Unable to fully drain due to configuration. Unable to check for
water
Accumulation continued over 3
shifts.
C50 filled C3086 and C3087 with water
•Inlet flow control valve in automatic – drove valve open.
•Board operator assumed water makeup valve blocked in field
•Field operator left water inlet valve open in field.
•No written work instruction.
•Delayed restart.
•Accumulation not recognized – sent material to refinery
•No alarm on chimney tray
•Unit surveillance reduced during outages.
•Drain point is higher than lowest level – left water in pup.
•Normal protocol while shutdown
Acid Cause Tree Overview
Acid was in the pup
Acid back flowed in C3087 via the C49 Feed Pump seal flush
Latent Acidity – Possible Minor Contributor discussed separately
Acid is in the feed tank
(T42) to C49
Seal Flush line connects T42 to
C3087
Seal Flush Check Valve
Failed
Pressure at seal greater than
C3087
No positive isolation on seal flush
Potential shutdown & operating condition
•Process always contains fat acid
•Fat acid phase level high enough to flow into pump.
•Valves open or leaking by.
•Seal flush valves left open while pump out of service – common practice.•Occurred several times
during shutdowns in Jan and Feb.
•Occurred during operation in 06 and 07
•Plug corroded
•Potential obstruction due to particulates
•Seal flush line added before March 1996.
.
Time Cause Tree OverviewThe pup remained in service
until it was below the pressure retaining capability
Belief all water removed
PT unaware of magnitude of seal
flush backflow PEI not aware
All acid backflow incidents not recognized.
Scenario not pre-identified. CS
used in Fat Acid
Accelerated corrosion rate unknown
In 2004 predicted half life was 2020
PT unaware of consequence of fat
acid in C3087
•Drained bullets and pup until thought dry.
•Unable to confirm whether dry.
•Fat acid found at bottom of C3087, potential consequence not understood.
•Not alerted by PT.
•PEI unaware of abnormal situation
•Awareness and response to foreign material in reboiler
•Critical pieces of info held individually.
•Root cause determination of control valve failures