Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2024-08-14 — TX
Operator
Energy Transfer Company
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$189,500
Incident datetime
2024-08-14 00:00 UTC
Report number
Location
TX
Narrative
On july 15, 2024, a rupture occurred on energy transfer companys k to coya 24-inch pipeline located approximately 15 miles southwest of monahans, tx. At 3:30 a.M. Supervisory control and data acquisition (scada) system alerted the coyanosa gas plant operator of a loss of pressure. At 4:40 a.M. The pipeline operator arrived on location to find local first responders were already on scene battling a fire. The emergency personnel had been notified of the fire by a third party. At 5:20 a.M. The affected pipeline was isolated, and the fire had burned out, energy transfer personnel were able to confirm the discovery of a rupture on the k to coya 24. It was determined the repairs and damages would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The local fire department allowed the fire to burn itself out. The cause of the rupture is still under investigation. The cause of the rupture was identified as external corrosion occurring along the 3:00 oclock side of the pipe. The thinnest measured remaining wall thickness was determined to be 0.020-inch (7% of the nominal wall thickness). Other areas of corrosion present on the pipe material provided appeared consistent with dc interference current corrosion and under deposit corrosion. Plan to prevent recurrence, operations will install more cp test stations to help locate external corrosion trouble areas and install more rectifiers to impress current equally over the entirety of the pipeline. Operations will also utilize corrosion coupons and chemical injection to monitor and mitigate any internal corrosion.
Detailed record list
Report Received Date
2024-08-14 00:00:00
Iyear
2024
Report Number
20240102
Supplemental Number
40038
Report Type
Supplemental Final
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
31.382919
Location Longitude
-103.048516
Nrc Rpt Num
1404780
Additional Nrc Report Numbers
1404966
Commodity Released Type
Natural Gas
Unintentional Release
14550
Intentional Release
1880
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
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Ignite Ind
Yes
How Extinguished
Allowed To Burn Out
Gas Consumed By Fire In Mcf
14550
Explode 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
79730
Onshore City Name
Coyanosa
Onshore County Name
Pecos
Designated Location
Milepost
Designated Name
608 + 00
Pipe Fac Name
K To Coya 24 Tx-Pecos_blk Ow,8
Segment Name
K To Coya 24 Tx-Pecos_blk Ow,8
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
48
Other Underground Facilities
No
Crossing
No
Pipe Facility Type
Intrastate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
24
Puddle Weld Ind
No
Pipe Wall Thickness
0.281
Pipe Smys
60000
Pipe Specification
X-60
Pipe Seam Type
Dsaw
Pipe Manufacturer
Unknown
Pipe Coating Type
Other
Pipe Coating Details
Wax
Coating Applied Ind
Unknown
Installation Year
1965
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
600
Rupture Width
24
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
561
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
31137
Est Cost Intentional Release
4023
Est Cost Prop Damage
189500
Est Cost Emergency
5000
Est Cost Other
0
Gas Cost In Mcf
2.14
Prpty
229660
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
650
Gas Flow In Pipe In Mcf
43.8
Mop Psig
1024
Mop Cfr Section
192.619(A)(3)
Maop Established Date
2013-12-05 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
122285
Internal Inspection Ind
No
Other Inspection Ind
Yes
Internal Inspection Details
No Launchers And Receivers
Operation Complications Ind
Yes
Other Complications Ind
Yes
Inspect Comp Details
No Launchers And Receivers
Pipeline Function
Type C Gathering
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
Yes
Scada Conf Ind
No
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
The investigation identified no controller issues. The controller actions were consistent with company protocols.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
General Corrosion
Stray Current Corrosion Ind
Yes
Microbiological Corrosion Ind
Yes
Stray Current Type
Direct Current
Stray Current Details
Adjacent Parallel Pipeline
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
1981
Shielding Evident
Yes
Cathodic Survey Type
No
Prior Damage
No
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2024
Hydrtst Most Rcnt Pressure
1550
Direct Asmnt Conducted
Yes, And An Investigative Dig Was Cunducted At The Point Of The Accident
Direct Asmnt At Pnt Accdnt Yr
2024
Asmnt Ecda Rcnt Year
2023
Asmnt Icda Rcnt Year
2023
Asmnt Ecda Rcnt Ind
Yes
Asmnt Icda Rcnt Ind
Yes
Non Destructive Exam Ind
Yes
Exm Handl Ultrasonic Rcnt Year
2023
Exm Handl Ultrasonic Rcnt Ind
Yes
Preparer Name
T*** P******
Preparer Title
Sr. Specialist Dot Compliance
Preparer Email
T***********@e*************.com
Preparer Telephone
432-423-2069
Authorizer Name
J***** D*******
Authorizer Title
Manager Dot Compliance
Authorizer Telephone
713-989-5231
Authorizer Email
J**************@e*************.com
Narrative
On july 15, 2024, a rupture occurred on energy transfer companys k to coya 24-inch pipeline located approximately 15 miles southwest of monahans, tx. At 3:30 a.M. Supervisory control and data acquisition (scada) system alerted the coyanosa gas plant operator of a loss of pressure. At 4:40 a.M. The pipeline operator arrived on location to find local first responders were already on scene battling a fire. The emergency personnel had been notified of the fire by a third party. At 5:20 a.M. The affected pipeline was isolated, and the fire had burned out, energy transfer personnel were able to confirm the discovery of a rupture on the k to coya 24. It was determined the repairs and damages would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The local fire department allowed the fire to burn itself out. The cause of the rupture is still under investigation. The cause of the rupture was identified as external corrosion occurring along the 3:00 oclock side of the pipe. The thinnest measured remaining wall thickness was determined to be 0.020-inch (7% of the nominal wall thickness). Other areas of corrosion present on the pipe material provided appeared consistent with dc interference current corrosion and under deposit corrosion. Plan to prevent recurrence, operations will install more cp test stations to help locate external corrosion trouble areas and install more rectifiers to impress current equally over the entirety of the pipeline. Operations will also utilize corrosion coupons and chemical injection to monitor and mitigate any internal corrosion.
| Report Received Date | 2024-08-14 00:00:00 |
|---|---|
| Iyear | 2024 |
| Report Number | 20240102 |
| Supplemental Number | 40038 |
| Report Type | Supplemental Final |
| 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 | 31.382919 Google Maps OpenStreetMap |
| Location Longitude | -103.048516 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1404780 NRC Report How to search |
| Additional Nrc Report Numbers | 1404966 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 14550 |
| Intentional Release | 1880 |
| 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 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Ignite Ind | Yes |
| How Extinguished | Allowed To Burn Out |
| Gas Consumed By Fire In Mcf | 14550 |
| Explode 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 | 79730 |
| Onshore City Name | Coyanosa |
| Onshore County Name | Pecos |
| Designated Location | Milepost |
| Designated Name | 608 + 00 |
| Pipe Fac Name | K To Coya 24 Tx-Pecos_blk Ow,8 |
| Segment Name | K To Coya 24 Tx-Pecos_blk Ow,8 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 48 |
| Other Underground Facilities | No |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 24 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.281 |
| Pipe Smys | 60000 |
| Pipe Specification | X-60 |
| Pipe Seam Type | Dsaw |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Other |
| Pipe Coating Details | Wax |
| Coating Applied Ind | Unknown |
| Installation Year | 1965 |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 600 |
| Rupture Width | 24 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 561 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 31137 |
| Est Cost Intentional Release | 4023 |
| Est Cost Prop Damage | 189500 |
| Est Cost Emergency | 5000 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 2.14 |
| Prpty | 229660 |
| 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 | 650 |
| Gas Flow In Pipe In Mcf | 43.8 |
| Mop Psig | 1024 |
| Mop Cfr Section | 192.619(A)(3) View CFR 49 §192 |
| Maop Established Date | 2013-12-05 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 | 122285 |
| Internal Inspection Ind | No |
| Other Inspection Ind | Yes |
| Internal Inspection Details | No Launchers And Receivers |
| Operation Complications Ind | Yes |
| Other Complications Ind | Yes |
| Inspect Comp Details | No Launchers And Receivers |
| Pipeline Function | Type C Gathering |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | Yes |
| Scada Conf Ind | No |
| 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 | The investigation identified no controller issues. The controller actions were consistent with company protocols. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | General Corrosion |
| Stray Current Corrosion Ind | Yes |
| Microbiological Corrosion Ind | Yes |
| Stray Current Type | Direct Current |
| Stray Current Details | Adjacent Parallel Pipeline |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 1981 |
| Shielding Evident | Yes |
| Cathodic Survey Type | No |
| Prior Damage | No |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2024 |
| Hydrtst Most Rcnt Pressure | 1550 |
| Direct Asmnt Conducted | Yes, And An Investigative Dig Was Cunducted At The Point Of The Accident |
| Direct Asmnt At Pnt Accdnt Yr | 2024 |
| Asmnt Ecda Rcnt Year | 2023 |
| Asmnt Icda Rcnt Year | 2023 |
| Asmnt Ecda Rcnt Ind | Yes |
| Asmnt Icda Rcnt Ind | Yes |
| Non Destructive Exam Ind | Yes |
| Exm Handl Ultrasonic Rcnt Year | 2023 |
| Exm Handl Ultrasonic Rcnt Ind | Yes |
| Preparer Name | T*** P****** |
| Preparer Title | Sr. Specialist Dot Compliance |
| Preparer Email | T***********@e*************.com |
| Preparer Telephone | 432-423-2069 |
| Authorizer Name | J***** D******* |
| Authorizer Title | Manager Dot Compliance |
| Authorizer Telephone | 713-989-5231 |
| Authorizer Email | J**************@e*************.com |
| Narrative | On july 15, 2024, a rupture occurred on energy transfer companys k to coya 24-inch pipeline located approximately 15 miles southwest of monahans, tx. At 3:30 a.M. Supervisory control and data acquisition (scada) system alerted the coyanosa gas plant operator of a loss of pressure. At 4:40 a.M. The pipeline operator arrived on location to find local first responders were already on scene battling a fire. The emergency personnel had been notified of the fire by a third party. At 5:20 a.M. The affected pipeline was isolated, and the fire had burned out, energy transfer personnel were able to confirm the discovery of a rupture on the k to coya 24. It was determined the repairs and damages would exceed the $145,400.00 reportable dollar criteria and the nrc and the txrrc were notified. The local fire department allowed the fire to burn itself out. The cause of the rupture is still under investigation. The cause of the rupture was identified as external corrosion occurring along the 3:00 oclock side of the pipe. The thinnest measured remaining wall thickness was determined to be 0.020-inch (7% of the nominal wall thickness). Other areas of corrosion present on the pipe material provided appeared consistent with dc interference current corrosion and under deposit corrosion. Plan to prevent recurrence, operations will install more cp test stations to help locate external corrosion trouble areas and install more rectifiers to impress current equally over the entirety of the pipeline. Operations will also utilize corrosion coupons and chemical injection to monitor and mitigate any internal corrosion. |
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