Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2012-10-15 — OK
Operator
Oneok Westex Transmission, Llc
Cause
Material Failure Of Pipe Or Weld
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$2,000
Incident datetime
2012-10-15 10:15
Report number
Location
OK
Narrative
Oneok westex transmission was conducting ecda confirmation digs on 6 inch diameter pipeline 0420-000 on monday october 15, 2012 utilizing a third party contractor. The contractor had uncovered the pipeline and two contractor personnel were in the ditch removing the old coating in preparation for recoating the pipeline. At approximately 1015 hours, the pipeline split open longitudinally releasing natural gas and the contractor personnel immediately left the ditch. There was no fire, no explosion, and no injuries. The local sheriff was notified and the 5-7 nearby structures were evacuated as a precautionary measure only. Line pressure at the time of the incident was 132 psi which was reduced to 84 psi to minimize hazards. Initial gas loss calculations and estimated repair costs were determined to be less than reportable limits. The railroad commission of texas was provided a courtesy call at 1236 hours. Further assessment of the damaged pipe resulted in a decision to repair via pipe replacement. This would cause a loss of natural gas service downstream of the incident site to the town of stanton with an estimated 850 customers. The national response center was provided a courtesy call at 1454 hours (incident number 1027378) based on the loss of service to the town of stanton. The railroad commission of texas was notified of the nrc incident number (texas incident number 755). The town of stanton went down at 1430 hours in preparation for the pipe replacement. Repairs were completed and evacuated structures released for occupancy by 1900 hours the same day. Full service to all customers and approval to relight occurred at 2145 hours. The delay between the completion of the pipe repair and relight was because a small 2 inch meter had to be utilized to pressure up the line and it took some time to achieve full line pressure. Further refined gas loss calculation results caused this incident to become reportable based on greater than 3 mmcf unintentional release of natural gas. The entire joint of pipe where the split occurred was replaced (total of 23.5 feet). A failure analysis is in process to determine the cause of the rupture. Update: failure analysis by external third party was inconclusive so the cause of the long seam weld failure could not be determined. In addition to the failure analysis of the failed longitudinal seam, a segment from the same joint of pipe adjacent to the seam failure portion was hydrotested to failure at 1500+ psig. Part g5 amended to reflect this. The incident costs and authorized signature information were also updated. This is a supplemental and final incident report.
Detailed record list
Report Received Date
2012-11-14 00:00:00
Iyear
2012
Report Number
20120112
Supplemental Number
16199
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
2012-10-15 10:15:00
Location Latitude
32.07206
Location Longitude
-101.92871
Nrc Rpt Num
1027378
Nrc Rpt Datetime
2012-10-15 14:54:00
Commodity Released Type
Natural Gas
Unintentional Release
3649
Intentional Release
216
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2012-10-15 14:30:00
Restart Datetime
2012-10-15 21:45:00
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
10
Incident Identified Datetime
2012-10-15 10:15:00
On Site Datetime
2012-10-15 10:15:00
On Off Shore
Onshore
Onshore State Abbreviation
Tx
Onshore Postal Code
79705
Onshore City Name
Midland
Onshore County Name
Midland
Pipe Fac Name
0420-000
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Crossing
No
Pipe Facility Type
Intrastate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Seam
Pipe Diameter
6.625
Pipe Wall Thickness
0.203
Pipe Smys
24000
Pipe Specification
Api 5l?
Pipe Seam Type
Lap Welded
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Installation Year
1928
Manufactured Year
1928
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
19
Rupture Width
0.4
Class Location Type
Class 2 Location
Could Be Hca
No
Pir Radius
180
Heat Damage Ind
No
Non Heat Damage Ind
No
Hca Fatalities Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
13027
Est Cost Intentional Release
771
Est Cost Prop Damage
2000
Est Cost Emergency
10000
Est Cost Other
0
Prpty
25798
Accident Psig
132
Mop Psig
307
Mop Cfr Section
Not On Omb-Approved Form When Submitted
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
92717
Internal Inspection Ind
No
Diameter Change 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
No
Scada Conf Ind
No
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Contractor Working For The Operator
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
Controllers or control room issues did not contribute to this incident. Oneok partners contractor personnel were onsite at the time of the incident.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Material Failure Of Pipe Or Weld
Cause Details
Original Manufacturing-Related (Not Girth Weld Or Other Welds Formed In The Field)
Pwjf Failure Type
Original Manufacturing-Related (Not Girth Weld Or Other Welds Formed In The Field)
Metallurgical Ind
Yes
Other Analysis Ind
Yes
Other Analysis Details
See Part H Narrative
Other Factor
Yes
Other Factor Details
See Part H Narrative
Pwf Additional Other Ind
Yes
Additional Other Details
See Part H Narrative
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
1971
Hydrtst Most Rcnt Pressure
460
Direct Asmnt Conducted
Yes, And An Investigative Dig Was Cunducted At The Point Of The Accident
Direct Asmnt At Pnt Accdnt Yr
2012
Non Destructive Exam Ind
No
Preparer Name
P**** F***
Preparer Title
Senior Pipeline Safety Engineer
Preparer Email
P*********@o****.com
Preparer Telephone
918 588 7131
Preparer Fax
918 732 1311
Authorizer Name
W***** R* D*****
Authorizer Title
Vice President
Authorizer Telephone
918 588 7424
Authorizer Email
W*********@o****.com
Narrative
Oneok westex transmission was conducting ecda confirmation digs on 6 inch diameter pipeline 0420-000 on monday october 15, 2012 utilizing a third party contractor. The contractor had uncovered the pipeline and two contractor personnel were in the ditch removing the old coating in preparation for recoating the pipeline. At approximately 1015 hours, the pipeline split open longitudinally releasing natural gas and the contractor personnel immediately left the ditch. There was no fire, no explosion, and no injuries. The local sheriff was notified and the 5-7 nearby structures were evacuated as a precautionary measure only. Line pressure at the time of the incident was 132 psi which was reduced to 84 psi to minimize hazards. Initial gas loss calculations and estimated repair costs were determined to be less than reportable limits. The railroad commission of texas was provided a courtesy call at 1236 hours. Further assessment of the damaged pipe resulted in a decision to repair via pipe replacement. This would cause a loss of natural gas service downstream of the incident site to the town of stanton with an estimated 850 customers. The national response center was provided a courtesy call at 1454 hours (incident number 1027378) based on the loss of service to the town of stanton. The railroad commission of texas was notified of the nrc incident number (texas incident number 755). The town of stanton went down at 1430 hours in preparation for the pipe replacement. Repairs were completed and evacuated structures released for occupancy by 1900 hours the same day. Full service to all customers and approval to relight occurred at 2145 hours. The delay between the completion of the pipe repair and relight was because a small 2 inch meter had to be utilized to pressure up the line and it took some time to achieve full line pressure. Further refined gas loss calculation results caused this incident to become reportable based on greater than 3 mmcf unintentional release of natural gas. The entire joint of pipe where the split occurred was replaced (total of 23.5 feet). A failure analysis is in process to determine the cause of the rupture. Update: failure analysis by external third party was inconclusive so the cause of the long seam weld failure could not be determined. In addition to the failure analysis of the failed longitudinal seam, a segment from the same joint of pipe adjacent to the seam failure portion was hydrotested to failure at 1500+ psig. Part g5 amended to reflect this. The incident costs and authorized signature information were also updated. This is a supplemental and final incident report.
| Report Received Date | 2012-11-14 00:00:00 |
|---|---|
| Iyear | 2012 |
| Report Number | 20120112 |
| Supplemental Number | 16199 |
| 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 | 2012-10-15 10:15:00 |
| Location Latitude | 32.07206 Google Maps OpenStreetMap |
| Location Longitude | -101.92871 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1027378 NRC Report How to search |
| Nrc Rpt Datetime | 2012-10-15 14:54:00 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 3649 |
| Intentional Release | 216 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2012-10-15 14:30:00 |
| Restart Datetime | 2012-10-15 21:45:00 |
| Ignite Ind | No |
| Explode Ind | No |
| Num Pub Evacuated | 10 |
| Incident Identified Datetime | 2012-10-15 10:15:00 |
| On Site Datetime | 2012-10-15 10:15:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 79705 |
| Onshore City Name | Midland |
| Onshore County Name | Midland |
| Pipe Fac Name | 0420-000 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Seam |
| Pipe Diameter | 6.625 |
| Pipe Wall Thickness | 0.203 |
| Pipe Smys | 24000 |
| Pipe Specification | Api 5l? |
| Pipe Seam Type | Lap Welded |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Installation Year | 1928 |
| Manufactured Year | 1928 |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 19 |
| Rupture Width | 0.4 |
| Class Location Type | Class 2 Location |
| Could Be Hca | No |
| Pir Radius | 180 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Hca Fatalities Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 13027 |
| Est Cost Intentional Release | 771 |
| Est Cost Prop Damage | 2000 |
| Est Cost Emergency | 10000 |
| Est Cost Other | 0 |
| Prpty | 25798 |
| Accident Psig | 132 |
| Mop Psig | 307 |
| Mop Cfr Section | Not On Omb-Approved Form When Submitted 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 | 92717 |
| Internal Inspection Ind | No |
| Diameter Change 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 | No |
| Scada Conf Ind | No |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Contractor Working For The Operator |
| 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 | Controllers or control room issues did not contribute to this incident. Oneok partners contractor personnel were onsite at the time of the incident. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Material Failure Of Pipe Or Weld |
| Cause Details | Original Manufacturing-Related (Not Girth Weld Or Other Welds Formed In The Field) |
| Pwjf Failure Type | Original Manufacturing-Related (Not Girth Weld Or Other Welds Formed In The Field) |
| Metallurgical Ind | Yes |
| Other Analysis Ind | Yes |
| Other Analysis Details | See Part H Narrative |
| Other Factor | Yes |
| Other Factor Details | See Part H Narrative |
| Pwf Additional Other Ind | Yes |
| Additional Other Details | See Part H Narrative |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 1971 |
| Hydrtst Most Rcnt Pressure | 460 |
| Direct Asmnt Conducted | Yes, And An Investigative Dig Was Cunducted At The Point Of The Accident |
| Direct Asmnt At Pnt Accdnt Yr | 2012 |
| Non Destructive Exam Ind | No |
| Preparer Name | P**** F*** |
| Preparer Title | Senior Pipeline Safety Engineer |
| Preparer Email | P*********@o****.com |
| Preparer Telephone | 918 588 7131 |
| Preparer Fax | 918 732 1311 |
| Authorizer Name | W***** R* D***** |
| Authorizer Title | Vice President |
| Authorizer Telephone | 918 588 7424 |
| Authorizer Email | W*********@o****.com |
| Narrative | Oneok westex transmission was conducting ecda confirmation digs on 6 inch diameter pipeline 0420-000 on monday october 15, 2012 utilizing a third party contractor. The contractor had uncovered the pipeline and two contractor personnel were in the ditch removing the old coating in preparation for recoating the pipeline. At approximately 1015 hours, the pipeline split open longitudinally releasing natural gas and the contractor personnel immediately left the ditch. There was no fire, no explosion, and no injuries. The local sheriff was notified and the 5-7 nearby structures were evacuated as a precautionary measure only. Line pressure at the time of the incident was 132 psi which was reduced to 84 psi to minimize hazards. Initial gas loss calculations and estimated repair costs were determined to be less than reportable limits. The railroad commission of texas was provided a courtesy call at 1236 hours. Further assessment of the damaged pipe resulted in a decision to repair via pipe replacement. This would cause a loss of natural gas service downstream of the incident site to the town of stanton with an estimated 850 customers. The national response center was provided a courtesy call at 1454 hours (incident number 1027378) based on the loss of service to the town of stanton. The railroad commission of texas was notified of the nrc incident number (texas incident number 755). The town of stanton went down at 1430 hours in preparation for the pipe replacement. Repairs were completed and evacuated structures released for occupancy by 1900 hours the same day. Full service to all customers and approval to relight occurred at 2145 hours. The delay between the completion of the pipe repair and relight was because a small 2 inch meter had to be utilized to pressure up the line and it took some time to achieve full line pressure. Further refined gas loss calculation results caused this incident to become reportable based on greater than 3 mmcf unintentional release of natural gas. The entire joint of pipe where the split occurred was replaced (total of 23.5 feet). A failure analysis is in process to determine the cause of the rupture. Update: failure analysis by external third party was inconclusive so the cause of the long seam weld failure could not be determined. In addition to the failure analysis of the failed longitudinal seam, a segment from the same joint of pipe adjacent to the seam failure portion was hydrotested to failure at 1500+ psig. Part g5 amended to reflect this. The incident costs and authorized signature information were also updated. This is a supplemental and final incident report. |
External Resources
PHMSA pipeline safety insights.
Product
Features
Company
All rights reserved. Copyright © by ClearPHMSA