Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2015-09-09 — TX
Operator
Texas Gas Transmission, Llc
Cause
Material Failure Of Pipe Or Weld
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$207,439
Incident datetime
2015-09-09 16:33
Report number
Location
TX
Narrative
Texas gas experienced a pipeline failure of its main line system 26" no. 1 line in union parish, louisiana. There were no injuries. The cause remains under investigation. 3-15-16 update to finalize report including cost and cause. Based on stress engineering's visual examination and metallurgical analyses of the samples provided, along with observations from a visit to the site, ses concluded that the monroe failure was caused by a combination of corrosion and near-neutral ph stress corrosion cracking. The information available to ses did not allow a determination of the precise timing or exact conditions that led to the failure. However, it was apparent that corrosion enlarged cracks in the pipe, thereby significantly contributing to the failure. The mechanical properties of the pipe material were tested and found to meet the requirements of API 5lx in effect in 1948 (as well as current requirements). While the material toughness was low, this property alone did not play a significant role in the failure. 4-29-16 revised cause on part g to reflect laboratory analysis findings. 5-23-16 revised per PHMSA request to report cause under section g5 instead g1.
Detailed record list
Report Received Date
2015-10-08 00:00:00
Iyear
2015
Report Number
20150120
Supplemental Number
17094
Report Type
Supplemental Final
Operator Id
19270
Name
Texas Gas Transmission, Llc
Operator Street Address
9 Greenway Plaza Suite 2800
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77046
Local Datetime
2015-09-09 16:30:00
Location Latitude
32.848632
Location Longitude
-92.285693
Nrc Rpt Num
1128025
Nrc Rpt Datetime
2015-09-09 17:23:00
Commodity Released Type
Natural Gas
Unintentional Release
42100
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Shutdown Due Accident Ind
No
Shutdown Explain
Rerouted Gas Flow
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
16
Incident Identified Datetime
2015-09-09 16:33:00
On Site Datetime
2015-09-09 17:30:00
On Off Shore
Onshore
Onshore State Abbreviation
La
Onshore Postal Code
71241
Onshore City Name
Farmerville
Onshore County Name
Union
Designated Location
Milepost
Designated Name
28+4276
Pipe Fac Name
Main Line System
Segment Name
Mls
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
48
Crossing
No
Pipe Facility Type
Interstate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
26
Pipe Wall Thickness
0.281
Pipe Smys
52000
Pipe Specification
Api 5l
Pipe Seam Type
Flash Welded
Pipe Manufacturer
A. O. Smith
Pipe Coating Type
Coal Tar
Installation Year
1949
Manufactured Year
1949
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
552
Rupture Width
26
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
511
Heat Damage Ind
No
Non Heat Damage Ind
No
Hca Fatalities Ind
No
Est Cost Oper Paid
5000
Est Cost Unintentional Release
133367
Est Cost Intentional Release
114655
Est Cost Prop Damage
207439
Est Cost Emergency
7500
Est Cost Other
0
Prpty
467961
Accident Psig
766
Mop Psig
810
Mop Cfr Section
192.619(A)(1)
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
52800
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
Transmission System
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
Yes
Scada Conf Ind
Yes
Accident Identifier
Notification From Emergency Responder
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
Incident occurred at a pressure below maop
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Material Failure Of Pipe Or Weld
Cause Details
Environmental Cracking-Related
Pwjf Failure Type
Environmental Cracking-Related
Field Exam Ind
Yes
Metallurgical Ind
Yes
Stress Subtype
Stress Corrosion Cracking
Additional Dent Ind
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
1976
Hydrtst Most Rcnt Pressure
1012
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
S****** M********
Preparer Title
Oq And Pa Coordinator
Preparer Email
S****************@b*****.com
Preparer Telephone
2706886357
Preparer Fax
2706886948
Authorizer Name
J****** B* M******
Authorizer Title
Manager Codes And Standards
Authorizer Telephone
2706886361
Authorizer Email
J***********@b*****.com
Narrative
Texas gas experienced a pipeline failure of its main line system 26" no. 1 line in union parish, louisiana. There were no injuries. The cause remains under investigation. 3-15-16 update to finalize report including cost and cause. Based on stress engineering's visual examination and metallurgical analyses of the samples provided, along with observations from a visit to the site, ses concluded that the monroe failure was caused by a combination of corrosion and near-neutral ph stress corrosion cracking. The information available to ses did not allow a determination of the precise timing or exact conditions that led to the failure. However, it was apparent that corrosion enlarged cracks in the pipe, thereby significantly contributing to the failure. The mechanical properties of the pipe material were tested and found to meet the requirements of API 5lx in effect in 1948 (as well as current requirements). While the material toughness was low, this property alone did not play a significant role in the failure. 4-29-16 revised cause on part g to reflect laboratory analysis findings. 5-23-16 revised per PHMSA request to report cause under section g5 instead g1.
| Report Received Date | 2015-10-08 00:00:00 |
|---|---|
| Iyear | 2015 |
| Report Number | 20150120 |
| Supplemental Number | 17094 |
| Report Type | Supplemental Final |
| Operator Id | 19270 PHMSA Enforcement |
| Name | Texas Gas Transmission, Llc |
| Operator Street Address | 9 Greenway Plaza Suite 2800 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77046 |
| Local Datetime | 2015-09-09 16:30:00 |
| Location Latitude | 32.848632 Google Maps OpenStreetMap |
| Location Longitude | -92.285693 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1128025 NRC Report How to search |
| Nrc Rpt Datetime | 2015-09-09 17:23:00 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 42100 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Shutdown Due Accident Ind | No |
| Shutdown Explain | Rerouted Gas Flow |
| Ignite Ind | No |
| Explode Ind | No |
| Num Pub Evacuated | 16 |
| Incident Identified Datetime | 2015-09-09 16:33:00 |
| On Site Datetime | 2015-09-09 17:30:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | La |
| Onshore Postal Code | 71241 |
| Onshore City Name | Farmerville |
| Onshore County Name | Union |
| Designated Location | Milepost |
| Designated Name | 28+4276 |
| Pipe Fac Name | Main Line System |
| Segment Name | Mls |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 48 |
| Crossing | No |
| Pipe Facility Type | Interstate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 26 |
| Pipe Wall Thickness | 0.281 |
| Pipe Smys | 52000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Flash Welded |
| Pipe Manufacturer | A. O. Smith |
| Pipe Coating Type | Coal Tar |
| Installation Year | 1949 |
| Manufactured Year | 1949 |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 552 |
| Rupture Width | 26 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 511 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Hca Fatalities Ind | No |
| Est Cost Oper Paid | 5000 |
| Est Cost Unintentional Release | 133367 |
| Est Cost Intentional Release | 114655 |
| Est Cost Prop Damage | 207439 |
| Est Cost Emergency | 7500 |
| Est Cost Other | 0 |
| Prpty | 467961 |
| Accident Psig | 766 |
| Mop Psig | 810 |
| Mop Cfr Section | 192.619(A)(1) View CFR 49 §192 |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 52800 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | Transmission System |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | Yes |
| Scada Conf Ind | Yes |
| Accident Identifier | Notification From Emergency Responder |
| 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 | Incident occurred at a pressure below maop |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Material Failure Of Pipe Or Weld |
| Cause Details | Environmental Cracking-Related |
| Pwjf Failure Type | Environmental Cracking-Related |
| Field Exam Ind | Yes |
| Metallurgical Ind | Yes |
| Stress Subtype | Stress Corrosion Cracking |
| Additional Dent Ind | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 1976 |
| Hydrtst Most Rcnt Pressure | 1012 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | S****** M******** |
| Preparer Title | Oq And Pa Coordinator |
| Preparer Email | S****************@b*****.com |
| Preparer Telephone | 2706886357 |
| Preparer Fax | 2706886948 |
| Authorizer Name | J****** B* M****** |
| Authorizer Title | Manager Codes And Standards |
| Authorizer Telephone | 2706886361 |
| Authorizer Email | J***********@b*****.com |
| Narrative | Texas gas experienced a pipeline failure of its main line system 26" no. 1 line in union parish, louisiana. There were no injuries. The cause remains under investigation. 3-15-16 update to finalize report including cost and cause. Based on stress engineering's visual examination and metallurgical analyses of the samples provided, along with observations from a visit to the site, ses concluded that the monroe failure was caused by a combination of corrosion and near-neutral ph stress corrosion cracking. The information available to ses did not allow a determination of the precise timing or exact conditions that led to the failure. However, it was apparent that corrosion enlarged cracks in the pipe, thereby significantly contributing to the failure. The mechanical properties of the pipe material were tested and found to meet the requirements of API 5lx in effect in 1948 (as well as current requirements). While the material toughness was low, this property alone did not play a significant role in the failure. 4-29-16 revised cause on part g to reflect laboratory analysis findings. 5-23-16 revised per PHMSA request to report cause under section g5 instead g1. |
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