Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2010-07-10 — TX
Operator
Enterprise Products Operating Llc
Cause
Other Accident Cause
Commodity
Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$173,000
Incident datetime
2010-07-10 15:00
Report number
Location
TX
Narrative
The pipeline was shut in at 1520 hrs on 07/08/2010 and monitored the pressure to determine if the leak in the row containing 9 pipelines. There were 3 other lines in the row carrying propylene. This was a very small leak that was noticeable only because it was raining with bubbling in the water. We caught a vapor sample of the gas and delivered to the mont belvieu lab which verified it was propylene. At approximately 1900, 07-08-10 pipeline compliance was notified that there was a leak in the row near our line but we had not verified that it was our line and explained what we were doing to monitor the line through the night. We monitored the pressure on our pipeline for approximately 6.5 hours and had a 22 psig pressure drop on the pipeline. This was not conclusive that the leak was ours but that it may be since there was a small drop in pipeline pressure. The rrc contacted enterprise representative on the scene at the time of the road closure and he explained that we did not know if the leak was ours. We gave the rrc representative the phone numbers of the other pipeline companies in the row and they contacted them to return to the site to further review their systems. At approximately 1800 on 07-09-10 we discussed the progress we were making with pipeline compliance and again stated we did not know if it was our leak. I also informed him that the rrc wanted to be contacted when the leak was identified. When the stopple was excavated and the flange was attempted to be removed it was found that the completion plug was leaking and we could not use the stopple. At this time our only alternative was to clear the entire section of pipeline (7.5 miles) from the valve on the west side of red bluff to morgan's point. We diverted the portable flare that was to be used at red bluff to morgan's point and started flaring at approximately 2030 hours on friday, 07-09-10. We manned the leak site while flaring through the night. We determined we could expedite clearing of the line by setting up a second flare at the east side of red bluff and use the tor fitting to flare the line at this location. At approximately 1000 saturday morning, 07-10-10 we started the second flare. By approximately 2100 hours the line pressure had dropped to 10 psig. At this time nitrogen was pumped into the line from the valve site on the west side of red bluff displacing to the morgan's point flare. This was continued through the night. On sunday, 07-11-10 the line was inert and the leak site was excavated. When excavation was complete, the line was swept with nitrogen and the leak site was identified at approximately 1700. Notified pipeline compliance that the leak was ours at approximately 1800 on sunday, 07-11-10, but still did not meet reporting volume. We proceeded to repair the pipeline and prepare for commissioning on monday, 07-12-10. Failure cause determination pending failure analysis lab results.
Detailed record list
Report Received Date
2010-08-05 00:00:00
Iyear
2010
Report Number
20100165
Supplemental Number
15285
Report Type
Supplemental Final
Operator Id
31618
Name
Enterprise Products Operating Llc
Operator Street Address
1100 Louisiana Street
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2010-07-08 15:20:00
Location Latitude
29.62478
Location Longitude
-95.09823
Commodity Released Type
Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions
Commodity Subtype
Lpg (Liquefied Petroleum Gas) / Ngl (Natural Gas Liquid)
Unintentional Release Bbls
7.52
Intentional Release Bbls
980
Recovered Bbls
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
Incident Identified Datetime
2010-07-10 15:00:00
System Part Involved
Onshore Pipeline, Including Valve Sites
On Off Shore
Onshore
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2010-07-08 15:20:00
Restart Datetime
2010-07-12 16:00:00
On Site Datetime
2010-07-10 15:01:00
Ignite Ind
No
Explode Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Remotely Controlled
Num Pub Evacuated
0
Pipe Fac Name
Morgans Point To Texas Olefins #3
Segment Name
914b-100
Onshore State Abbreviation
Tx
Onshore Postal Code
77507
Onshore City Name
Pasadena
Onshore County Name
Harris
Designated Location
Survey Station No.
Designated Name
396+17
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
6.625
Pipe Wall Thickness
0.25
Pipe Smys
42000
Pipe Specification
Api 5l X42
Pipe Seam Type
Erw � Unknown Frequency
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Installation Year
1997
Manufactured Year
1997
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Other
Leak Type Other
Failure Pending Lab Results
Wildlife Impact Ind
No
Soil Contamination
No
Long Term Assessment
No
Remediation Ind
No
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
75917
Est Cost Prop Damage
173000
Est Cost Emergency
12400
Prpty
261317
Accident Psig
229
Mop Psig
1440
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction Ind
No
Length Segment Isolated
39600
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
> 20% Smys Regulated Transmission
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
No
Scada Conf Ind
No
Cpm In Place Ind
No
Investigation Status
No, the operator did not find that an investigation of the controller(s) actions or control room issues was necessary due to: (provide an explanation for why the operator did not investigate)
Investigation Status Details
Crack in pipeline girth weld.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Other Accident Cause
Cause Details
Miscellaneous
Other Type
Miscellaneous
Misc Details
The Root Cause Of The Leak Was A Crack Within A Damaged Area On The Inside Surface Of The Pipe Presumably Caused By A Cleaning Tool. The Cleaning Tool Did Not Transition The Long Radius (1.5 D) Elbow Sufficiently Resulting In The Nose Of The Tool Impacting The Downstream Girth Weld Of The 45-Degree Elbow. The Recent Cpig Tools Run Through The Pipeline Do Not Appear To Have Caused The Damage To The Pipeline. The Vibration Of The Metal Loss Tool Could Have Contributed To The Opening Of The Pre-
Preparer Name
J*** J*****
Preparer Title
Compliance Specialist
Preparer Email
J******@e****.com
Preparer Telephone
7133817918
Preparer Fax
7133818790
Prepared Date
2010-09-08 00:00:00
Authorizer Name
J*** J*****
Authorizer Telephone
7133817918
Authorizer Title
Compliance Specialist
Authorizer Email
J******@e****.com
Narrative
The pipeline was shut in at 1520 hrs on 07/08/2010 and monitored the pressure to determine if the leak in the row containing 9 pipelines. There were 3 other lines in the row carrying propylene. This was a very small leak that was noticeable only because it was raining with bubbling in the water. We caught a vapor sample of the gas and delivered to the mont belvieu lab which verified it was propylene. At approximately 1900, 07-08-10 pipeline compliance was notified that there was a leak in the row near our line but we had not verified that it was our line and explained what we were doing to monitor the line through the night. We monitored the pressure on our pipeline for approximately 6.5 hours and had a 22 psig pressure drop on the pipeline. This was not conclusive that the leak was ours but that it may be since there was a small drop in pipeline pressure. The rrc contacted enterprise representative on the scene at the time of the road closure and he explained that we did not know if the leak was ours. We gave the rrc representative the phone numbers of the other pipeline companies in the row and they contacted them to return to the site to further review their systems. At approximately 1800 on 07-09-10 we discussed the progress we were making with pipeline compliance and again stated we did not know if it was our leak. I also informed him that the rrc wanted to be contacted when the leak was identified. When the stopple was excavated and the flange was attempted to be removed it was found that the completion plug was leaking and we could not use the stopple. At this time our only alternative was to clear the entire section of pipeline (7.5 miles) from the valve on the west side of red bluff to morgan's point. We diverted the portable flare that was to be used at red bluff to morgan's point and started flaring at approximately 2030 hours on friday, 07-09-10. We manned the leak site while flaring through the night. We determined we could expedite clearing of the line by setting up a second flare at the east side of red bluff and use the tor fitting to flare the line at this location. At approximately 1000 saturday morning, 07-10-10 we started the second flare. By approximately 2100 hours the line pressure had dropped to 10 psig. At this time nitrogen was pumped into the line from the valve site on the west side of red bluff displacing to the morgan's point flare. This was continued through the night. On sunday, 07-11-10 the line was inert and the leak site was excavated. When excavation was complete, the line was swept with nitrogen and the leak site was identified at approximately 1700. Notified pipeline compliance that the leak was ours at approximately 1800 on sunday, 07-11-10, but still did not meet reporting volume. We proceeded to repair the pipeline and prepare for commissioning on monday, 07-12-10. Failure cause determination pending failure analysis lab results.
| Report Received Date | 2010-08-05 00:00:00 |
|---|---|
| Iyear | 2010 |
| Report Number | 20100165 |
| Supplemental Number | 15285 |
| Report Type | Supplemental Final |
| Operator Id | 31618 PHMSA Enforcement |
| Name | Enterprise Products Operating Llc |
| Operator Street Address | 1100 Louisiana Street |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2010-07-08 15:20:00 |
| Location Latitude | 29.62478 Google Maps OpenStreetMap |
| Location Longitude | -95.09823 Google Maps OpenStreetMap |
| Commodity Released Type | Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions |
| Commodity Subtype | Lpg (Liquefied Petroleum Gas) / Ngl (Natural Gas Liquid) |
| Unintentional Release Bbls | 7.52 |
| Intentional Release Bbls | 980 |
| Recovered Bbls | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| Incident Identified Datetime | 2010-07-10 15:00:00 |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2010-07-08 15:20:00 |
| Restart Datetime | 2010-07-12 16:00:00 |
| On Site Datetime | 2010-07-10 15:01:00 |
| Ignite Ind | No |
| Explode Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Remotely Controlled |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Morgans Point To Texas Olefins #3 |
| Segment Name | 914b-100 |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 77507 |
| Onshore City Name | Pasadena |
| Onshore County Name | Harris |
| Designated Location | Survey Station No. |
| Designated Name | 396+17 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 6.625 |
| Pipe Wall Thickness | 0.25 |
| Pipe Smys | 42000 |
| Pipe Specification | Api 5l X42 |
| Pipe Seam Type | Erw � Unknown Frequency |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Installation Year | 1997 |
| Manufactured Year | 1997 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Other |
| Leak Type Other | Failure Pending Lab Results |
| Wildlife Impact Ind | No |
| Soil Contamination | No |
| Long Term Assessment | No |
| Remediation Ind | No |
| 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 | 75917 |
| Est Cost Prop Damage | 173000 |
| Est Cost Emergency | 12400 |
| Prpty | 261317 |
| Accident Psig | 229 |
| Mop Psig | 1440 |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction Ind | No |
| Length Segment Isolated | 39600 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | > 20% Smys Regulated Transmission |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | No |
| Scada Conf Ind | No |
| Cpm In Place Ind | No |
| Investigation Status | No, the operator did not find that an investigation of the controller(s) actions or control room issues was necessary due to: (provide an explanation for why the operator did not investigate) |
| Investigation Status Details | Crack in pipeline girth weld. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Other Accident Cause |
| Cause Details | Miscellaneous |
| Other Type | Miscellaneous |
| Misc Details | The Root Cause Of The Leak Was A Crack Within A Damaged Area On The Inside Surface Of The Pipe Presumably Caused By A Cleaning Tool. The Cleaning Tool Did Not Transition The Long Radius (1.5 D) Elbow Sufficiently Resulting In The Nose Of The Tool Impacting The Downstream Girth Weld Of The 45-Degree Elbow. The Recent Cpig Tools Run Through The Pipeline Do Not Appear To Have Caused The Damage To The Pipeline. The Vibration Of The Metal Loss Tool Could Have Contributed To The Opening Of The Pre- |
| Preparer Name | J*** J***** |
| Preparer Title | Compliance Specialist |
| Preparer Email | J******@e****.com |
| Preparer Telephone | 7133817918 |
| Preparer Fax | 7133818790 |
| Prepared Date | 2010-09-08 00:00:00 |
| Authorizer Name | J*** J***** |
| Authorizer Telephone | 7133817918 |
| Authorizer Title | Compliance Specialist |
| Authorizer Email | J******@e****.com |
| Narrative | The pipeline was shut in at 1520 hrs on 07/08/2010 and monitored the pressure to determine if the leak in the row containing 9 pipelines. There were 3 other lines in the row carrying propylene. This was a very small leak that was noticeable only because it was raining with bubbling in the water. We caught a vapor sample of the gas and delivered to the mont belvieu lab which verified it was propylene. At approximately 1900, 07-08-10 pipeline compliance was notified that there was a leak in the row near our line but we had not verified that it was our line and explained what we were doing to monitor the line through the night. We monitored the pressure on our pipeline for approximately 6.5 hours and had a 22 psig pressure drop on the pipeline. This was not conclusive that the leak was ours but that it may be since there was a small drop in pipeline pressure. The rrc contacted enterprise representative on the scene at the time of the road closure and he explained that we did not know if the leak was ours. We gave the rrc representative the phone numbers of the other pipeline companies in the row and they contacted them to return to the site to further review their systems. At approximately 1800 on 07-09-10 we discussed the progress we were making with pipeline compliance and again stated we did not know if it was our leak. I also informed him that the rrc wanted to be contacted when the leak was identified. When the stopple was excavated and the flange was attempted to be removed it was found that the completion plug was leaking and we could not use the stopple. At this time our only alternative was to clear the entire section of pipeline (7.5 miles) from the valve on the west side of red bluff to morgan's point. We diverted the portable flare that was to be used at red bluff to morgan's point and started flaring at approximately 2030 hours on friday, 07-09-10. We manned the leak site while flaring through the night. We determined we could expedite clearing of the line by setting up a second flare at the east side of red bluff and use the tor fitting to flare the line at this location. At approximately 1000 saturday morning, 07-10-10 we started the second flare. By approximately 2100 hours the line pressure had dropped to 10 psig. At this time nitrogen was pumped into the line from the valve site on the west side of red bluff displacing to the morgan's point flare. This was continued through the night. On sunday, 07-11-10 the line was inert and the leak site was excavated. When excavation was complete, the line was swept with nitrogen and the leak site was identified at approximately 1700. Notified pipeline compliance that the leak was ours at approximately 1800 on sunday, 07-11-10, but still did not meet reporting volume. We proceeded to repair the pipeline and prepare for commissioning on monday, 07-12-10. Failure cause determination pending failure analysis lab results. |
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