Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2014-04-08 — GA
Operator
Colonial Pipeline Co
Cause
Corrosion Failure
Commodity
Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$25
Incident datetime
2014-04-08 18:00
Report number
Location
GA
Narrative
On the morning of april 8 2014, operations required the drain down and backfill of the manifold due to kerosene being brought into the tank farm. It had been raining through the night and the rain continued into the morning. The operator was doing a walk-around inside the oil manifold late tuesday afternoon when he noticed a strong odor of petroleum near the incoming tank valve header. The operator used a msa altair lel detector to check for vapors but got a reading of zero. The operator contacted the environmental specialist to inform her and ask for assistance to locate the source of the odor. The environmental specialist was able to detect vapor levels - using an ultra rae monitor - in the monitoring wells along the main line oil header. The slotted pvc piping used to check for ground water contamination confirmed that there was indeed product in the monitoring wells along the row of valves at the oil header. Initial indication revealed a potentially small release so the acting operations manager and the district project leader formed a crew to excavate the next morning. Local notification was made to the director of operations and environmental manager that evening. The next morning the crew began digging along the main line and roanoke header valve and found a cracked 1 inch schedule 80 drain line between roanoke tank valves 973 and 974. Permanent repairs were made on the drain line by cutting out and replacing the 1 inch tee and a foot of 1 inch schedule 80 pipe. Clean up and monitoring activities continued until april 15th, 2014, at which time the recovered accumulation remained at 20 gallons. Product recovered included approximately 3 gallons in soil, 6 gallons in free product and 11 gallons in absorbents from open excavation. As of april 22, 2014, no sign of additional product has been detected.
Detailed record list
Report Received Date
2014-04-30 00:00:00
Iyear
2014
Report Number
20140172
Supplemental Number
19337
Report Type
Original Final
Operator Id
2552
Name
Colonial Pipeline Co
Operator Street Address
1000 Lake St.
Operator City Name
Alpharetta
Operator State Abbreviation
GA
Operator Postal Code
30009
Local Datetime
2014-04-08 18:00:00
Location Latitude
37.66399
Location Longitude
-78.239171
Commodity Released Type
Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions
Commodity Subtype
Diesel, Fuel Oil, Kerosene, Jet Fuel
Unintentional Release Bbls
0.48
Recovered Bbls
0.48
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Incident Identified Datetime
2014-04-08 18:00:00
System Part Involved
Onshore Pump/meter Station Equipment And Piping
On Off Shore
Onshore
Shutdown Due Accident Ind
No
Shutdown Explain
Occurred At A Cracked Drain Line Inside A Tank Manifold That Was Not Operational
On Site Datetime
2014-04-08 18:00:00
Ignite Ind
No
Explode Ind
No
Pipe Fac Name
Mitchell Junction
Onshore State Abbreviation
Va
Onshore Postal Code
23038
Onshore City Name
Columbia
Onshore County Name
Cumberland
Designated Location
Milepost/valve Station
Designated Name
946
Federal
No
Location Type
Totally Contained On Operator-Controlled Property
Incident Area Type
Underground
Pipe Facility Type
Interstate
Item Involved
Auxiliary Piping (E.g. Drain Lines)
Release Type
Leak
Leak Type
Crack
Water Contam Ind
No
Could Be Hca
Yes
Commodity Reached Hca
Yes
Other Pop Ind
Yes
Other Pop Yes No
Yes
Usa Drinking Ind
Yes
Usa Drinking Yes No
Yes
Est Cost Oper Paid
0
Est Cost Gas Released
76
Est Cost Prop Damage
25
Est Cost Emergency
18000
Est Cost Environmental
0
Est Cost Other
0
Prpty
18101
Pipeline Function
> 20% Smys Regulated Transmission
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Preparer Name
A**** S****
Preparer Title
Compliance Coordinator
Preparer Email
A******@c******.com
Preparer Telephone
410 970 2157
Preparer Fax
770 754 8036
Prepared Date
2014-04-30 00:00:00
Authorizer Name
A**** M** T*****
Authorizer Telephone
678 762 2872
Authorizer Title
Regulatory Manager
Authorizer Email
A******@c******.com
Narrative
On the morning of april 8 2014, operations required the drain down and backfill of the manifold due to kerosene being brought into the tank farm. It had been raining through the night and the rain continued into the morning. The operator was doing a walk-around inside the oil manifold late tuesday afternoon when he noticed a strong odor of petroleum near the incoming tank valve header. The operator used a msa altair lel detector to check for vapors but got a reading of zero. The operator contacted the environmental specialist to inform her and ask for assistance to locate the source of the odor. The environmental specialist was able to detect vapor levels - using an ultra rae monitor - in the monitoring wells along the main line oil header. The slotted pvc piping used to check for ground water contamination confirmed that there was indeed product in the monitoring wells along the row of valves at the oil header. Initial indication revealed a potentially small release so the acting operations manager and the district project leader formed a crew to excavate the next morning. Local notification was made to the director of operations and environmental manager that evening. The next morning the crew began digging along the main line and roanoke header valve and found a cracked 1 inch schedule 80 drain line between roanoke tank valves 973 and 974. Permanent repairs were made on the drain line by cutting out and replacing the 1 inch tee and a foot of 1 inch schedule 80 pipe. Clean up and monitoring activities continued until april 15th, 2014, at which time the recovered accumulation remained at 20 gallons. Product recovered included approximately 3 gallons in soil, 6 gallons in free product and 11 gallons in absorbents from open excavation. As of april 22, 2014, no sign of additional product has been detected.
| Report Received Date | 2014-04-30 00:00:00 |
|---|---|
| Iyear | 2014 |
| Report Number | 20140172 |
| Supplemental Number | 19337 |
| Report Type | Original Final |
| Operator Id | 2552 PHMSA Enforcement |
| Name | Colonial Pipeline Co |
| Operator Street Address | 1000 Lake St. |
| Operator City Name | Alpharetta |
| Operator State Abbreviation | GA |
| Operator Postal Code | 30009 |
| Local Datetime | 2014-04-08 18:00:00 |
| Location Latitude | 37.66399 Google Maps OpenStreetMap |
| Location Longitude | -78.239171 Google Maps OpenStreetMap |
| Commodity Released Type | Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions |
| Commodity Subtype | Diesel, Fuel Oil, Kerosene, Jet Fuel |
| Unintentional Release Bbls | 0.48 |
| Recovered Bbls | 0.48 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Incident Identified Datetime | 2014-04-08 18:00:00 |
| System Part Involved | Onshore Pump/meter Station Equipment And Piping |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | No |
| Shutdown Explain | Occurred At A Cracked Drain Line Inside A Tank Manifold That Was Not Operational |
| On Site Datetime | 2014-04-08 18:00:00 |
| Ignite Ind | No |
| Explode Ind | No |
| Pipe Fac Name | Mitchell Junction |
| Onshore State Abbreviation | Va |
| Onshore Postal Code | 23038 |
| Onshore City Name | Columbia |
| Onshore County Name | Cumberland |
| Designated Location | Milepost/valve Station |
| Designated Name | 946 |
| Federal | No |
| Location Type | Totally Contained On Operator-Controlled Property |
| Incident Area Type | Underground |
| Pipe Facility Type | Interstate |
| Item Involved | Auxiliary Piping (E.g. Drain Lines) |
| Release Type | Leak |
| Leak Type | Crack |
| Water Contam Ind | No |
| Could Be Hca | Yes |
| Commodity Reached Hca | Yes |
| Other Pop Ind | Yes |
| Other Pop Yes No | Yes |
| Usa Drinking Ind | Yes |
| Usa Drinking Yes No | Yes |
| Est Cost Oper Paid | 0 |
| Est Cost Gas Released | 76 |
| Est Cost Prop Damage | 25 |
| Est Cost Emergency | 18000 |
| Est Cost Environmental | 0 |
| Est Cost Other | 0 |
| Prpty | 18101 |
| Pipeline Function | > 20% Smys Regulated Transmission |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Preparer Name | A**** S**** |
| Preparer Title | Compliance Coordinator |
| Preparer Email | A******@c******.com |
| Preparer Telephone | 410 970 2157 |
| Preparer Fax | 770 754 8036 |
| Prepared Date | 2014-04-30 00:00:00 |
| Authorizer Name | A**** M** T***** |
| Authorizer Telephone | 678 762 2872 |
| Authorizer Title | Regulatory Manager |
| Authorizer Email | A******@c******.com |
| Narrative | On the morning of april 8 2014, operations required the drain down and backfill of the manifold due to kerosene being brought into the tank farm. It had been raining through the night and the rain continued into the morning. The operator was doing a walk-around inside the oil manifold late tuesday afternoon when he noticed a strong odor of petroleum near the incoming tank valve header. The operator used a msa altair lel detector to check for vapors but got a reading of zero. The operator contacted the environmental specialist to inform her and ask for assistance to locate the source of the odor. The environmental specialist was able to detect vapor levels - using an ultra rae monitor - in the monitoring wells along the main line oil header. The slotted pvc piping used to check for ground water contamination confirmed that there was indeed product in the monitoring wells along the row of valves at the oil header. Initial indication revealed a potentially small release so the acting operations manager and the district project leader formed a crew to excavate the next morning. Local notification was made to the director of operations and environmental manager that evening. The next morning the crew began digging along the main line and roanoke header valve and found a cracked 1 inch schedule 80 drain line between roanoke tank valves 973 and 974. Permanent repairs were made on the drain line by cutting out and replacing the 1 inch tee and a foot of 1 inch schedule 80 pipe. Clean up and monitoring activities continued until april 15th, 2014, at which time the recovered accumulation remained at 20 gallons. Product recovered included approximately 3 gallons in soil, 6 gallons in free product and 11 gallons in absorbents from open excavation. As of april 22, 2014, no sign of additional product has been detected. |
External Resources
PHMSA pipeline safety insights.
Product
Features
Company
All rights reserved. Copyright © by ClearPHMSA