Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2024-12-13 — TX
Operator
Gulf South Pipeline Company, Llc
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$345,000
Incident datetime
2024-12-13 00:00 UTC
Report number
Location
TX
Narrative
On 11/24/24 at approximately 20:56, a pipeline rupture occurred on gulf south's bistineau storage field well line a-11, also referred to as index 900-8. The rupture was initially identified by a gulf south operations employee who lives onsite. The bi-directional 8-inch o.D. Well line connects the single a-11 well to the a lateral pipeline trunk between the compressor station field header and the storage field. The a-11 well was shut in, along with the corresponding valves located on the a lateral trunk pipeline, allowing gulf south to totally isolate the affected well line from the storage field and compressor station field header. This enabled the affected line segment to be fully depressurized. The line segment remained isolated and depressurized until a pipe replacement was completed. Repair was completed on 12/11/24 by pipe replacement. The failed section of pipe and a short pup from each end of the remaining pipe were inspected on site by gulf south's metallurgist, wrapped, and sent to a lab for further analysis which has not yet been completed. The field examination determined the preliminary cause of the failure to be internal corrosion. Additionally, PHMSA asked how this pipeline is treated. It is treated using a continuous injection pump. A corrosion inhibitor, specifically coastal chemical 1141-c, is injected when the field is in withdrawal mode. On average, 0.25 to 0.5 gallons per day of chemical is pumped. 1/24/25 updated response to c3g and part h per PHMSA request.
Detailed record list
Report Received Date
2024-12-13 00:00:00
Iyear
2024
Report Number
20240136
Supplemental Number
40436
Report Type
Supplemental Final
Operator Id
31728
Name
Gulf South Pipeline Company, Llc
Operator Street Address
9 Greenway Plaza Suite 2800
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77046
Time Zone
Central
Daylight Savings Ind
No
Location Latitude
32.380544
Location Longitude
-93.354831
Nrc Rpt Num
1417264
Additional Nrc Report Numbers
1417394
Commodity Released Type
Natural Gas
Unintentional Release
50
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
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Ignite Ind
No
Upstream Action Taken
Valve Closure
Downstream Action Taken
Valve Closure
Num Pub Evacuated
0
On Off Shore
Onshore
Onshore State Abbreviation
La
Onshore Postal Code
71068
Onshore City Name
Ringgold
Onshore County Name
Bienville
Designated Location
Survey Station No.
Designated Name
1+70
Pipe Fac Name
Bistineau Storage Field A-11 Well Line
Segment Name
Index 900-8
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
8.625
Puddle Weld Ind
No
Pipe Wall Thickness
0.312
Pipe Smys
52000
Pipe Specification
Api 5lx
Pipe Seam Type
Seamless
Pipe Manufacturer
Us Steel
Pipe Coating Type
Coal Tar
Coating Applied Ind
Yes
Installation Year
1969
Manufactured Year
1969
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
84
Rupture Width
24
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
284
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
118
Est Cost Intentional Release
0
Est Cost Prop Damage
345000
Est Cost Emergency
2000
Est Cost Other
0
Gas Cost In Mcf
2.35
Prpty
347118
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
1790
Gas Flow In Pipe In Mcf
1500
Mop Psig
2160
Mop Cfr Section
192.619(A)(1)
Maop Established Date
1970-11-12 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
975
Internal Inspection Ind
Yes
Operation Complications Ind
Yes
Other Complications Ind
Yes
Inspect Comp Details
No Permanent Launcher Or Receiver.
Pipeline Function
Transmission In Storage Field
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
Operator Employee
Investigation Status
Yes, specify investigation result(s): (select all that apply)
Invest No Control Room Ind
Yes
Invest No Controller Ind
Yes
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
Localized Pitting
Int Water Acid Ind
Yes
Int Microbiological Ind
Yes
Int Field Exam Basis Ind
Yes
Int Low Point Pipe Loc Ind
Yes
Corrosion Inhibitors
Yes
Corrosion Lining
No
Cleaning Dewatering
No
Corrosion Coupons
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
S****** M********
Preparer Title
Compliance Program Leader
Preparer Email
S****************@b**********.com
Preparer Telephone
2709035764
Authorizer Name
T*** B****
Authorizer Title
Manager Compliance Services
Authorizer Telephone
2703146546
Authorizer Email
T*********@b**********.com
Narrative
On 11/24/24 at approximately 20:56, a pipeline rupture occurred on gulf south's bistineau storage field well line a-11, also referred to as index 900-8. The rupture was initially identified by a gulf south operations employee who lives onsite. The bi-directional 8-inch o.D. Well line connects the single a-11 well to the a lateral pipeline trunk between the compressor station field header and the storage field. The a-11 well was shut in, along with the corresponding valves located on the a lateral trunk pipeline, allowing gulf south to totally isolate the affected well line from the storage field and compressor station field header. This enabled the affected line segment to be fully depressurized. The line segment remained isolated and depressurized until a pipe replacement was completed. Repair was completed on 12/11/24 by pipe replacement. The failed section of pipe and a short pup from each end of the remaining pipe were inspected on site by gulf south's metallurgist, wrapped, and sent to a lab for further analysis which has not yet been completed. The field examination determined the preliminary cause of the failure to be internal corrosion. Additionally, PHMSA asked how this pipeline is treated. It is treated using a continuous injection pump. A corrosion inhibitor, specifically coastal chemical 1141-c, is injected when the field is in withdrawal mode. On average, 0.25 to 0.5 gallons per day of chemical is pumped. 1/24/25 updated response to c3g and part h per PHMSA request.
| Report Received Date | 2024-12-13 00:00:00 |
|---|---|
| Iyear | 2024 |
| Report Number | 20240136 |
| Supplemental Number | 40436 |
| Report Type | Supplemental Final |
| Operator Id | 31728 PHMSA Enforcement |
| Name | Gulf South Pipeline Company, Llc |
| Operator Street Address | 9 Greenway Plaza Suite 2800 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77046 |
| Time Zone | Central |
| Daylight Savings Ind | No |
| Location Latitude | 32.380544 Google Maps OpenStreetMap |
| Location Longitude | -93.354831 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1417264 NRC Report How to search |
| Additional Nrc Report Numbers | 1417394 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 50 |
| 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 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Downstream Action Taken | Valve Closure |
| Num Pub Evacuated | 0 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | La |
| Onshore Postal Code | 71068 |
| Onshore City Name | Ringgold |
| Onshore County Name | Bienville |
| Designated Location | Survey Station No. |
| Designated Name | 1+70 |
| Pipe Fac Name | Bistineau Storage Field A-11 Well Line |
| Segment Name | Index 900-8 |
| 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 | 8.625 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.312 |
| Pipe Smys | 52000 |
| Pipe Specification | Api 5lx |
| Pipe Seam Type | Seamless |
| Pipe Manufacturer | Us Steel |
| Pipe Coating Type | Coal Tar |
| Coating Applied Ind | Yes |
| Installation Year | 1969 |
| Manufactured Year | 1969 |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 84 |
| Rupture Width | 24 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 284 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 118 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 345000 |
| Est Cost Emergency | 2000 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 2.35 |
| Prpty | 347118 |
| 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 | 1790 |
| Gas Flow In Pipe In Mcf | 1500 |
| Mop Psig | 2160 |
| Mop Cfr Section | 192.619(A)(1) View CFR 49 §192 |
| Maop Established Date | 1970-11-12 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 | 975 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | Yes |
| Other Complications Ind | Yes |
| Inspect Comp Details | No Permanent Launcher Or Receiver. |
| Pipeline Function | Transmission In Storage Field |
| 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 | Operator Employee |
| Investigation Status | Yes, specify investigation result(s): (select all that apply) |
| Invest No Control Room Ind | Yes |
| Invest No Controller Ind | Yes |
| 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 | Localized Pitting |
| Int Water Acid Ind | Yes |
| Int Microbiological Ind | Yes |
| Int Field Exam Basis Ind | Yes |
| Int Low Point Pipe Loc Ind | Yes |
| Corrosion Inhibitors | Yes |
| Corrosion Lining | No |
| Cleaning Dewatering | No |
| Corrosion Coupons | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | S****** M******** |
| Preparer Title | Compliance Program Leader |
| Preparer Email | S****************@b**********.com |
| Preparer Telephone | 2709035764 |
| Authorizer Name | T*** B**** |
| Authorizer Title | Manager Compliance Services |
| Authorizer Telephone | 2703146546 |
| Authorizer Email | T*********@b**********.com |
| Narrative | On 11/24/24 at approximately 20:56, a pipeline rupture occurred on gulf south's bistineau storage field well line a-11, also referred to as index 900-8. The rupture was initially identified by a gulf south operations employee who lives onsite. The bi-directional 8-inch o.D. Well line connects the single a-11 well to the a lateral pipeline trunk between the compressor station field header and the storage field. The a-11 well was shut in, along with the corresponding valves located on the a lateral trunk pipeline, allowing gulf south to totally isolate the affected well line from the storage field and compressor station field header. This enabled the affected line segment to be fully depressurized. The line segment remained isolated and depressurized until a pipe replacement was completed. Repair was completed on 12/11/24 by pipe replacement. The failed section of pipe and a short pup from each end of the remaining pipe were inspected on site by gulf south's metallurgist, wrapped, and sent to a lab for further analysis which has not yet been completed. The field examination determined the preliminary cause of the failure to be internal corrosion. Additionally, PHMSA asked how this pipeline is treated. It is treated using a continuous injection pump. A corrosion inhibitor, specifically coastal chemical 1141-c, is injected when the field is in withdrawal mode. On average, 0.25 to 0.5 gallons per day of chemical is pumped. 1/24/25 updated response to c3g and part h per PHMSA request. |
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