Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2020-11-11 — TX
Operator
Columbia Gas Transmission, Llc
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$472,395
Incident datetime
2020-11-11 21:00
Report number
Location
TX
Narrative
On the evening of november 11th, 2020, storage field (sf) personnel from columbia gas transmission, llc (company), a tc energy entity, responded to an event at donegal storage field which is operated and maintained by the company. At 9:33 pm, company monitoring center personnel received a call from gas control regarding a pressure drop. The pressure had dropped from 1,190 to 1,156 psig, followed by a subsequent drop to 1,035 psig after shutting-in pressure regulation. At 9:35 pm, field personnel were contacted by a near-by property owner reporting the sound of a gas line leak; subsequently, company operations personnel were notified to respond to the event location. First responder arrived on scene at 9:45 pm and observed gas blowing; the local fire department closed cunningham road at this time. At 9:54 pm a company sf technician confirmed that the reported leak had been isolated by operating the critical valve. The national response center (nrc) and PHMSA accident incident division were contacted within 1 hour of confirmed discovery at 10:50 pm. Nrc one-hour (1291972) and 48-hr (1292099) reports were completed on november 11th and november 13th respectively. The failed storage line (9190) was secured and sent to a metallurgical failure analysis laboratory to evaluate and determine the probable cause behind this pipeline failure. The repair of the line consisted of pipe replacement. The metallurgical root cause of the failure was due to external corrosion identified along the 6:00 o'clock orientation of the pipe. The absence of an external coating and exposure to atmosphere (I.E. De-coupled from the soil electrolyte) were contributing factors to the corrosion of the pipe. In an effort to prevent future occurrence, the company has looked beyond this location to other segments with similar environmental conditions and pipe characteristics where corrosion may adversely impact line integrity; to that end, two opportunities for mitigative measures have been scheduled for completion before december 31, 2022. The projects will involve replacing line segments and assessment of the removed segments for external corrosion. Note: all times were recorded in eastern standard time
Detailed record list
Report Received Date
2020-12-10 00:00:00
Iyear
2020
Report Number
20200130
Supplemental Number
36535
Report Type
Supplemental Final
Operator Id
2616
Name
Columbia Gas Transmission, Llc
Operator Street Address
700 Louisiana St. Suite 700
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2020-11-11 21:49:00
Time Zone
Eastern
Daylight Savings Ind
Yes
Location Latitude
40.14085
Location Longitude
-80.4463
Nrc Rpt Num
1291972
Nrc Rpt Datetime
2020-11-11 22:50:00
Additional Nrc Report Numbers
1292099
Commodity Released Type
Natural Gas
Unintentional Release
7687.2
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Status When Identified
Normal Operation, Includes Pauses During Maintenance
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2020-11-11 21:49:00
Restart Datetime
2020-12-29 13:41:00
Communication State Fed Ind
Yes
Party Initiated Communication
Local/state/federal Emergency Responder
Initial Responder Com Datetime
2020-11-11 21:45:00
Ignite Ind
No
Upstream Action Taken
Valve Closure
Upstream Valve Close Datetime
2020-11-11 21:45:00
Downstream Action Taken
Valve Closure
Downstream Vlv Close Datetime
2020-11-11 21:45:00
Num Pub Evacuated
0
Incident Identified Datetime
2020-11-11 21:00:00
On Site Datetime
2020-11-11 21:49:00
On Off Shore
Onshore
Onshore State Abbreviation
Pa
Onshore Postal Code
15323
Onshore City Name
Claysville
Onshore County Name
Washington
Designated Location
Not Applicable
Pipe Fac Name
9190 / Donegal Storage Field Well 3951
Segment Name
9190
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
36
Other Underground Facilities
No
Crossing
No
Pipe Facility Type
Interstate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
4
Puddle Weld Ind
No
Pipe Wall Thickness
0.237
Pipe Smys
35000
Pipe Specification
Unknown
Pipe Seam Type
Seamless
Pipe Manufacturer
Unknown
Pipe Coating Type
None
Coating Applied Ind
No
Installation Year
1948
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Circumferential
Rupture Length
4.5
Rupture Width
4.5
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
99
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
17296
Est Cost Intentional Release
0
Est Cost Prop Damage
472395
Est Cost Emergency
0
Est Cost Other
84880
Est Cost Other Details
Investigation Costs
Gas Cost In Mcf
2.25
Prpty
574571
Num Persons Hosp Not Ovnght
0
Num Injured Treated By Emt
0
Num Resident Building Affctd
0
Num Business Building Affctd
0
Wildlife Impact Ind
No
Accident Psig
1117
Gas Flow In Pipe In Mcf
574350
Mop Psig
1280
Mop Cfr Section
192.619(A)(2)
Maop Established Date
1969-12-15 00:00:00
Maop Reversal Flow Ind
No
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Gas Required Odorized Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
472
Internal Inspection Ind
No
Unsuitable Mainline Ind
Yes
Operation Complications Ind
Yes
Other Complications Ind
Yes
Inspect Comp Details
Valve Type Is Plug
Pipeline Function
Transmission In Storage Field
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
Yes, specify investigation result(s): (select all that apply)
Invest No Control Room Ind
Yes
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
Other
Visual Exam Details
External Corrosion Along The 6:00 Orientation Of The Pipe
Galvanic Corrosion Ind
Yes
Atmosphere Corrosion Ind
Yes
Field Exam Basis Ind
Yes
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
1948
Shielding Evident
No
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Close Interval Survey Ind
Yes
Cp Annual Survey Year
2021
Close Interval Survey Year
2006
Prior Damage
N/a Bare/ineffectively Coated Pipe
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
1970
Hydrtst Most Rcnt Pressure
1786
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
B** H*****
Preparer Title
Compliance Specialist
Preparer Email
B*********@t*******.com
Preparer Telephone
304-539-9311
Authorizer Name
P*** S******
Authorizer Title
Manager Usrc East
Authorizer Telephone
304-550-4866
Authorizer Email
P***********@t*******.com
Narrative
On the evening of november 11th, 2020, storage field (sf) personnel from columbia gas transmission, llc (company), a tc energy entity, responded to an event at donegal storage field which is operated and maintained by the company. At 9:33 pm, company monitoring center personnel received a call from gas control regarding a pressure drop. The pressure had dropped from 1,190 to 1,156 psig, followed by a subsequent drop to 1,035 psig after shutting-in pressure regulation. At 9:35 pm, field personnel were contacted by a near-by property owner reporting the sound of a gas line leak; subsequently, company operations personnel were notified to respond to the event location. First responder arrived on scene at 9:45 pm and observed gas blowing; the local fire department closed cunningham road at this time. At 9:54 pm a company sf technician confirmed that the reported leak had been isolated by operating the critical valve. The national response center (nrc) and PHMSA accident incident division were contacted within 1 hour of confirmed discovery at 10:50 pm. Nrc one-hour (1291972) and 48-hr (1292099) reports were completed on november 11th and november 13th respectively. The failed storage line (9190) was secured and sent to a metallurgical failure analysis laboratory to evaluate and determine the probable cause behind this pipeline failure. The repair of the line consisted of pipe replacement. The metallurgical root cause of the failure was due to external corrosion identified along the 6:00 o'clock orientation of the pipe. The absence of an external coating and exposure to atmosphere (I.E. De-coupled from the soil electrolyte) were contributing factors to the corrosion of the pipe. In an effort to prevent future occurrence, the company has looked beyond this location to other segments with similar environmental conditions and pipe characteristics where corrosion may adversely impact line integrity; to that end, two opportunities for mitigative measures have been scheduled for completion before december 31, 2022. The projects will involve replacing line segments and assessment of the removed segments for external corrosion. Note: all times were recorded in eastern standard time
| Report Received Date | 2020-12-10 00:00:00 |
|---|---|
| Iyear | 2020 |
| Report Number | 20200130 |
| Supplemental Number | 36535 |
| Report Type | Supplemental Final |
| Operator Id | 2616 PHMSA Enforcement |
| Name | Columbia Gas Transmission, Llc |
| Operator Street Address | 700 Louisiana St. Suite 700 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2020-11-11 21:49:00 |
| Time Zone | Eastern |
| Daylight Savings Ind | Yes |
| Location Latitude | 40.14085 Google Maps OpenStreetMap |
| Location Longitude | -80.4463 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1291972 NRC Report How to search |
| Nrc Rpt Datetime | 2020-11-11 22:50:00 |
| Additional Nrc Report Numbers | 1292099 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 7687.2 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Status When Identified | Normal Operation, Includes Pauses During Maintenance |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2020-11-11 21:49:00 |
| Restart Datetime | 2020-12-29 13:41:00 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Local/state/federal Emergency Responder |
| Initial Responder Com Datetime | 2020-11-11 21:45:00 |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Upstream Valve Close Datetime | 2020-11-11 21:45:00 |
| Downstream Action Taken | Valve Closure |
| Downstream Vlv Close Datetime | 2020-11-11 21:45:00 |
| Num Pub Evacuated | 0 |
| Incident Identified Datetime | 2020-11-11 21:00:00 |
| On Site Datetime | 2020-11-11 21:49:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Pa |
| Onshore Postal Code | 15323 |
| Onshore City Name | Claysville |
| Onshore County Name | Washington |
| Designated Location | Not Applicable |
| Pipe Fac Name | 9190 / Donegal Storage Field Well 3951 |
| Segment Name | 9190 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 36 |
| Other Underground Facilities | No |
| Crossing | No |
| Pipe Facility Type | Interstate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 4 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.237 |
| Pipe Smys | 35000 |
| Pipe Specification | Unknown |
| Pipe Seam Type | Seamless |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | None |
| Coating Applied Ind | No |
| Installation Year | 1948 |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Circumferential |
| Rupture Length | 4.5 |
| Rupture Width | 4.5 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 99 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 17296 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 472395 |
| Est Cost Emergency | 0 |
| Est Cost Other | 84880 |
| Est Cost Other Details | Investigation Costs |
| Gas Cost In Mcf | 2.25 |
| Prpty | 574571 |
| Num Persons Hosp Not Ovnght | 0 |
| Num Injured Treated By Emt | 0 |
| Num Resident Building Affctd | 0 |
| Num Business Building Affctd | 0 |
| Wildlife Impact Ind | No |
| Accident Psig | 1117 |
| Gas Flow In Pipe In Mcf | 574350 |
| Mop Psig | 1280 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Maop Established Date | 1969-12-15 00:00:00 |
| Maop Reversal Flow Ind | No |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Gas Required Odorized Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 472 |
| Internal Inspection Ind | No |
| Unsuitable Mainline Ind | Yes |
| Operation Complications Ind | Yes |
| Other Complications Ind | Yes |
| Inspect Comp Details | Valve Type Is Plug |
| Pipeline Function | Transmission In Storage Field |
| 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 | Yes, specify investigation result(s): (select all that apply) |
| Invest No Control Room Ind | Yes |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | Other |
| Visual Exam Details | External Corrosion Along The 6:00 Orientation Of The Pipe |
| Galvanic Corrosion Ind | Yes |
| Atmosphere Corrosion Ind | Yes |
| Field Exam Basis Ind | Yes |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 1948 |
| Shielding Evident | No |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Close Interval Survey Ind | Yes |
| Cp Annual Survey Year | 2021 |
| Close Interval Survey Year | 2006 |
| Prior Damage | N/a Bare/ineffectively Coated Pipe |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 1970 |
| Hydrtst Most Rcnt Pressure | 1786 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | B** H***** |
| Preparer Title | Compliance Specialist |
| Preparer Email | B*********@t*******.com |
| Preparer Telephone | 304-539-9311 |
| Authorizer Name | P*** S****** |
| Authorizer Title | Manager Usrc East |
| Authorizer Telephone | 304-550-4866 |
| Authorizer Email | P***********@t*******.com |
| Narrative | On the evening of november 11th, 2020, storage field (sf) personnel from columbia gas transmission, llc (company), a tc energy entity, responded to an event at donegal storage field which is operated and maintained by the company. At 9:33 pm, company monitoring center personnel received a call from gas control regarding a pressure drop. The pressure had dropped from 1,190 to 1,156 psig, followed by a subsequent drop to 1,035 psig after shutting-in pressure regulation. At 9:35 pm, field personnel were contacted by a near-by property owner reporting the sound of a gas line leak; subsequently, company operations personnel were notified to respond to the event location. First responder arrived on scene at 9:45 pm and observed gas blowing; the local fire department closed cunningham road at this time. At 9:54 pm a company sf technician confirmed that the reported leak had been isolated by operating the critical valve. The national response center (nrc) and PHMSA accident incident division were contacted within 1 hour of confirmed discovery at 10:50 pm. Nrc one-hour (1291972) and 48-hr (1292099) reports were completed on november 11th and november 13th respectively. The failed storage line (9190) was secured and sent to a metallurgical failure analysis laboratory to evaluate and determine the probable cause behind this pipeline failure. The repair of the line consisted of pipe replacement. The metallurgical root cause of the failure was due to external corrosion identified along the 6:00 o'clock orientation of the pipe. The absence of an external coating and exposure to atmosphere (I.E. De-coupled from the soil electrolyte) were contributing factors to the corrosion of the pipe. In an effort to prevent future occurrence, the company has looked beyond this location to other segments with similar environmental conditions and pipe characteristics where corrosion may adversely impact line integrity; to that end, two opportunities for mitigative measures have been scheduled for completion before december 31, 2022. The projects will involve replacing line segments and assessment of the removed segments for external corrosion. Note: all times were recorded in eastern standard time |
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