Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2015-10-21 — OK
Operator
Oneok Westex Transmission, Llc
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$142,500
Incident datetime
2015-10-21 02:34
Report number
Location
OK
Narrative
At 2:32 am on oct 21, pipeline control operators noticed a pressure drop on line 4001-000. The control operator notified field operations personnel. Several mainline valves were closed to determine which section of the line might be leaking. When the leaking segment was identified, field operations personnel began following the pipeline to determine the location of the leak. At 8:55 am the location of the leak was identified. Approximately 100 feet of line had ruptured and was partially ejected from the ditch. At this time external corrosion is the suspected cause based on field examination on oct 21. The failure pieces have been sent to a third party lab for examination. A supplemental report will be filed if the root cause is determined to be something other than external corrosion. Supplemental - the lab report confirmed external corrosion as the cause of the failure.
Detailed record list
Report Received Date
2015-11-20 00:00:00
Iyear
2015
Report Number
20150138
Supplemental Number
17230
Report Type
Supplemental Final
Operator Id
31531
Name
Oneok Westex Transmission, Llc
Operator Street Address
100 West Fifth Street
Operator City Name
Tulsa
Operator State Abbreviation
OK
Operator Postal Code
74103
Local Datetime
2015-10-21 08:55:00
Location Latitude
31.35589
Location Longitude
-103.87945
Nrc Rpt Num
1131315
Nrc Rpt Datetime
2015-10-21 09:05:00
Commodity Released Type
Natural Gas
Unintentional Release
48641
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2015-10-21 07:28:00
Restart Datetime
2015-10-23 11:32:00
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
0
Incident Identified Datetime
2015-10-21 02:34:00
On Site Datetime
2015-10-21 04:04:00
On Off Shore
Onshore
Onshore State Abbreviation
Tx
Onshore Postal Code
79785
Onshore City Name
Not Within A Municipality
Onshore County Name
Reeves
Designated Location
Milepost
Designated Name
Mp 53.52
Pipe Fac Name
Owt Line 4001-000
Segment Name
Owt Line 4001-000
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
36
Crossing
No
Pipe Facility Type
Intrastate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
12.75
Pipe Wall Thickness
0.219
Pipe Smys
42000
Pipe Specification
Api 5lx
Pipe Seam Type
Longitudinal Erw - Unknown Frequency
Pipe Manufacturer
Jones&laughlin
Pipe Coating Type
Coal Tar
Installation Year
1968
Manufactured Year
1967
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
1200
Rupture Width
12
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
370
Heat Damage Ind
No
Non Heat Damage Ind
No
Hca Fatalities Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
118737
Est Cost Intentional Release
0
Est Cost Prop Damage
142500
Est Cost Emergency
1000
Est Cost Other
0
Prpty
262237
Accident Psig
877
Mop Psig
953
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
96730
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
Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Or Pack Calculations)
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
There was no investigation of the controller due to the response time was adequate and available controls were address/utilized. There were no indications of fatigue or stress based on his work schedule and again due to the response time fatigue did not play apart in this rupture.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
Localized Pitting
Galvanic Corrosion Ind
Yes
Field Exam Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
1968
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Cp Annual Survey Year
2015
Prior Damage
No
Collected Data Ind
Yes
Axial Magnetic Flx Lkg Ind
Yes
Geometry Deformation Ind
Yes
Axial Recent Year
2015
Geometry Recent Year
2015
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
Yes, But The Point Of The Accident Was Not Identified As A Dig Site
Direct Asmnt Pnt Not Idntf Yr
2006
Non Destructive Exam Ind
No
Preparer Name
P****** V******
Preparer Title
Manager Regulatory Compliance
Preparer Email
P**********@o****.com
Preparer Telephone
918-588-7734
Preparer Fax
918-591-5032
Authorizer Name
W** D*****
Authorizer Title
Vp Natural Gas Pipeline Operations
Authorizer Telephone
918-588-7424
Authorizer Email
W************@o****.com
Narrative
At 2:32 am on oct 21, pipeline control operators noticed a pressure drop on line 4001-000. The control operator notified field operations personnel. Several mainline valves were closed to determine which section of the line might be leaking. When the leaking segment was identified, field operations personnel began following the pipeline to determine the location of the leak. At 8:55 am the location of the leak was identified. Approximately 100 feet of line had ruptured and was partially ejected from the ditch. At this time external corrosion is the suspected cause based on field examination on oct 21. The failure pieces have been sent to a third party lab for examination. A supplemental report will be filed if the root cause is determined to be something other than external corrosion. Supplemental - the lab report confirmed external corrosion as the cause of the failure.
| Report Received Date | 2015-11-20 00:00:00 |
|---|---|
| Iyear | 2015 |
| Report Number | 20150138 |
| Supplemental Number | 17230 |
| Report Type | Supplemental Final |
| Operator Id | 31531 PHMSA Enforcement |
| Name | Oneok Westex Transmission, Llc |
| Operator Street Address | 100 West Fifth Street |
| Operator City Name | Tulsa |
| Operator State Abbreviation | OK |
| Operator Postal Code | 74103 |
| Local Datetime | 2015-10-21 08:55:00 |
| Location Latitude | 31.35589 Google Maps OpenStreetMap |
| Location Longitude | -103.87945 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1131315 NRC Report How to search |
| Nrc Rpt Datetime | 2015-10-21 09:05:00 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 48641 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2015-10-21 07:28:00 |
| Restart Datetime | 2015-10-23 11:32:00 |
| Ignite Ind | No |
| Explode Ind | No |
| Num Pub Evacuated | 0 |
| Incident Identified Datetime | 2015-10-21 02:34:00 |
| On Site Datetime | 2015-10-21 04:04:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 79785 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Reeves |
| Designated Location | Milepost |
| Designated Name | Mp 53.52 |
| Pipe Fac Name | Owt Line 4001-000 |
| Segment Name | Owt Line 4001-000 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 36 |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 12.75 |
| Pipe Wall Thickness | 0.219 |
| Pipe Smys | 42000 |
| Pipe Specification | Api 5lx |
| Pipe Seam Type | Longitudinal Erw - Unknown Frequency |
| Pipe Manufacturer | Jones&laughlin |
| Pipe Coating Type | Coal Tar |
| Installation Year | 1968 |
| Manufactured Year | 1967 |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 1200 |
| Rupture Width | 12 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 370 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Hca Fatalities Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 118737 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 142500 |
| Est Cost Emergency | 1000 |
| Est Cost Other | 0 |
| Prpty | 262237 |
| Accident Psig | 877 |
| Mop Psig | 953 |
| 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 | 96730 |
| 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 | Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Or Pack Calculations) |
| 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 | There was no investigation of the controller due to the response time was adequate and available controls were address/utilized. There were no indications of fatigue or stress based on his work schedule and again due to the response time fatigue did not play apart in this rupture. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | Localized Pitting |
| Galvanic Corrosion Ind | Yes |
| Field Exam Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 1968 |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Cp Annual Survey Year | 2015 |
| Prior Damage | No |
| Collected Data Ind | Yes |
| Axial Magnetic Flx Lkg Ind | Yes |
| Geometry Deformation Ind | Yes |
| Axial Recent Year | 2015 |
| Geometry Recent Year | 2015 |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | Yes, But The Point Of The Accident Was Not Identified As A Dig Site |
| Direct Asmnt Pnt Not Idntf Yr | 2006 |
| Non Destructive Exam Ind | No |
| Preparer Name | P****** V****** |
| Preparer Title | Manager Regulatory Compliance |
| Preparer Email | P**********@o****.com |
| Preparer Telephone | 918-588-7734 |
| Preparer Fax | 918-591-5032 |
| Authorizer Name | W** D***** |
| Authorizer Title | Vp Natural Gas Pipeline Operations |
| Authorizer Telephone | 918-588-7424 |
| Authorizer Email | W************@o****.com |
| Narrative | At 2:32 am on oct 21, pipeline control operators noticed a pressure drop on line 4001-000. The control operator notified field operations personnel. Several mainline valves were closed to determine which section of the line might be leaking. When the leaking segment was identified, field operations personnel began following the pipeline to determine the location of the leak. At 8:55 am the location of the leak was identified. Approximately 100 feet of line had ruptured and was partially ejected from the ditch. At this time external corrosion is the suspected cause based on field examination on oct 21. The failure pieces have been sent to a third party lab for examination. A supplemental report will be filed if the root cause is determined to be something other than external corrosion. Supplemental - the lab report confirmed external corrosion as the cause of the failure. |
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