Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2025-06-15 — TX
Operator
Energy Transfer Company
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$236,000
Incident datetime
2025-06-15 00:00 UTC
Report number
Location
TX
Narrative
On may 9, 2025, an incident occurred on the 210000 - perkins 10" hp to ft chadbourne, 6.14 miles southwest of silver, texas in coke county. At approximately 1930 the line had a release. It was determined to be a rupture that occurred during routine maintenance pigging operations. On may 16, 2025, at 1230, it was determined the repairs would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The line separation is still under investigation and the affected section of the pipe has been sent to the lab for analysis. A supplemental report will be submitted when the lab analysis and investigation is complete. **the lab results concluded that the failure coincides with a region of internal corrosion present along the bottom of the pipe. The internal corrosion occurred due to hydrogen sulfide and carbon dioxide combining with water to form an acidic environment. To prevent this from occurring in the future, operations will implement a pigging schedule and corrosion inhibitor program specific for the pipeline. Coupons will be added before the line is put back into service. A supplemental report will be submitted once the pipeline has been put back into service.
Detailed record list
Report Received Date
2025-06-15 00:00:00
Iyear
2025
Report Number
20250070
Supplemental Number
41301
Report Type
Supplemental
Operator Id
32099
Name
Energy Transfer Company
Operator Street Address
1300 Main Street
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Time Zone
Central
Daylight Savings Ind
Yes
Location Latitude
32.01373986
Location Longitude
-100.7604127
Nrc Rpt Num
1431278
Additional Nrc Report Numbers
1431410
Commodity Released Type
Natural Gas
Unintentional Release
192
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
Still Shutdown Ind
Yes
Communication State Fed Ind
No
Ignite Ind
No
Upstream Action Taken
Valve Closure
Downstream Action Taken
Valve Closure
Num Pub Evacuated
0
On Off Shore
Onshore
Onshore State Abbreviation
Tx
Onshore Postal Code
76949
Onshore City Name
Silver
Onshore County Name
Coke
Designated Location
Survey Station No.
Designated Name
49+96.5
Pipe Fac Name
Perkins 10'' Hp To Ft Chadbourne
Segment Name
210000
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
24
Other Underground Facilities
Yes
Crossing
No
Pipe Facility Type
Intrastate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
10.75
Puddle Weld Ind
No
Pipe Wall Thickness
0.365
Pipe Smys
24000
Pipe Specification
Unknown
Pipe Seam Type
Longitudinal Erw - Unknown Frequency
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Coating Applied Ind
Unknown
Installation Year
1965
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Circumferential
Rupture Length
10.8
Rupture Width
10.8
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
198
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
609
Est Cost Intentional Release
0
Est Cost Prop Damage
236000
Est Cost Emergency
1000
Est Cost Other
0
Gas Cost In Mcf
3.17
Prpty
237609
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
245
Gas Flow In Pipe In Mcf
538
Mop Psig
1440
Mop Cfr Section
192.619(A)(1)
Maop Established Date
1965-01-01 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
11299
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
Type C Gathering
Scada In Place Ind
No
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
Investigation Status
No, the facility was not monitored by a controller(s) at the time of the incident
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
Internal Corrosion
Internal External
Internal Corrosion
Int Visual Exam Results
General Corrosion
Int Water Acid Ind
Yes
Int Metallurgical Basis Ind
Yes
Int Low Point Pipe Loc Ind
Yes
Corrosion Inhibitors
Yes
Corrosion Lining
No
Cleaning Dewatering
No
Corrosion Coupons
No
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
C**** P******
Preparer Title
Sr. Specialist Dot Compliance
Preparer Email
C******************@e*************.com
Preparer Telephone
3259333577
Authorizer Name
J***** D*******
Authorizer Title
Manager Dot Compliance
Authorizer Telephone
7139895231
Authorizer Email
J**************@e*************.com
Narrative
On may 9, 2025, an incident occurred on the 210000 - perkins 10" hp to ft chadbourne, 6.14 miles southwest of silver, texas in coke county. At approximately 1930 the line had a release. It was determined to be a rupture that occurred during routine maintenance pigging operations. On may 16, 2025, at 1230, it was determined the repairs would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The line separation is still under investigation and the affected section of the pipe has been sent to the lab for analysis. A supplemental report will be submitted when the lab analysis and investigation is complete. **the lab results concluded that the failure coincides with a region of internal corrosion present along the bottom of the pipe. The internal corrosion occurred due to hydrogen sulfide and carbon dioxide combining with water to form an acidic environment. To prevent this from occurring in the future, operations will implement a pigging schedule and corrosion inhibitor program specific for the pipeline. Coupons will be added before the line is put back into service. A supplemental report will be submitted once the pipeline has been put back into service.
| Report Received Date | 2025-06-15 00:00:00 |
|---|---|
| Iyear | 2025 |
| Report Number | 20250070 |
| Supplemental Number | 41301 |
| Report Type | Supplemental |
| Operator Id | 32099 PHMSA Enforcement |
| Name | Energy Transfer Company |
| Operator Street Address | 1300 Main Street |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Time Zone | Central |
| Daylight Savings Ind | Yes |
| Location Latitude | 32.01373986 Google Maps OpenStreetMap |
| Location Longitude | -100.7604127 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1431278 NRC Report How to search |
| Additional Nrc Report Numbers | 1431410 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 192 |
| 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 |
| Still Shutdown Ind | Yes |
| Communication State Fed Ind | No |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Downstream Action Taken | Valve Closure |
| Num Pub Evacuated | 0 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 76949 |
| Onshore City Name | Silver |
| Onshore County Name | Coke |
| Designated Location | Survey Station No. |
| Designated Name | 49+96.5 |
| Pipe Fac Name | Perkins 10'' Hp To Ft Chadbourne |
| Segment Name | 210000 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 24 |
| Other Underground Facilities | Yes |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 10.75 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.365 |
| Pipe Smys | 24000 |
| Pipe Specification | Unknown |
| Pipe Seam Type | Longitudinal Erw - Unknown Frequency |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Coating Applied Ind | Unknown |
| Installation Year | 1965 |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Circumferential |
| Rupture Length | 10.8 |
| Rupture Width | 10.8 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 198 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 609 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 236000 |
| Est Cost Emergency | 1000 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 3.17 |
| Prpty | 237609 |
| 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 | 245 |
| Gas Flow In Pipe In Mcf | 538 |
| Mop Psig | 1440 |
| Mop Cfr Section | 192.619(A)(1) View CFR 49 §192 |
| Maop Established Date | 1965-01-01 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 | 11299 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | Type C Gathering |
| Scada In Place Ind | No |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| Investigation Status | No, the facility was not monitored by a controller(s) at the time of the incident |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | Internal Corrosion |
| Internal External | Internal Corrosion |
| Int Visual Exam Results | General Corrosion |
| Int Water Acid Ind | Yes |
| Int Metallurgical Basis Ind | Yes |
| Int Low Point Pipe Loc Ind | Yes |
| Corrosion Inhibitors | Yes |
| Corrosion Lining | No |
| Cleaning Dewatering | No |
| Corrosion Coupons | No |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | C**** P****** |
| Preparer Title | Sr. Specialist Dot Compliance |
| Preparer Email | C******************@e*************.com |
| Preparer Telephone | 3259333577 |
| Authorizer Name | J***** D******* |
| Authorizer Title | Manager Dot Compliance |
| Authorizer Telephone | 7139895231 |
| Authorizer Email | J**************@e*************.com |
| Narrative | On may 9, 2025, an incident occurred on the 210000 - perkins 10" hp to ft chadbourne, 6.14 miles southwest of silver, texas in coke county. At approximately 1930 the line had a release. It was determined to be a rupture that occurred during routine maintenance pigging operations. On may 16, 2025, at 1230, it was determined the repairs would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The line separation is still under investigation and the affected section of the pipe has been sent to the lab for analysis. A supplemental report will be submitted when the lab analysis and investigation is complete. **the lab results concluded that the failure coincides with a region of internal corrosion present along the bottom of the pipe. The internal corrosion occurred due to hydrogen sulfide and carbon dioxide combining with water to form an acidic environment. To prevent this from occurring in the future, operations will implement a pigging schedule and corrosion inhibitor program specific for the pipeline. Coupons will be added before the line is put back into service. A supplemental report will be submitted once the pipeline has been put back into service. |
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