Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2022-06-11 — TX
Operator
Targa Downstream Llc
Cause
Corrosion Failure
Commodity
Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$65,000
Incident datetime
2022-06-11 15:10
Report number
Location
TX
Narrative
At approximately 15:10 targa was contacted by 3rd party of a possible pipeline leak. Personnel were dispatched to site and pipeline control room was notified of possible leak. Targa personnel arrived on-site and found vapors slowly leaking out of ground with an ice sheet along the pipeline right-of-way. Line was verified to be targa's gateway lateral using maps, line locator & ice sheet matched properties of product being transported (hvl). On-site personnel began monitoring area for any unsafe conditions and based on rural location and weather conditions at time of leak there were no threats to public safety. Operations then began process of shutting down pipeline to stop leak. Due to the operational complexity of the system various processes had to take place to take the pipeline out of service safely. During this time on-site personnel continuously monitored leak ensuring area was kept safe. Pipeline was shut in and evacuated of product using nitrogen and pigging for repair and remediation processes to begin. Deformation and metal loss integrity assessed by ili was conducted on 4/7/2022. Final ili report was issued to targa on 6/6/22, 5 days before leak occurred, and contained no immediate repair conditions or src's. There were 60-day and 180-day repair conditions identified in ili report. The features identified were external & internal metal loss attributable to manufacturing related defects. All features found by ili were within a 300-foot section of pipeline, therefore targa elected to replace an entire 300-foot section of pipe to repair all features and to prevent recurrence of possible leak. Additionally, targa has initiated 3rd party investigations regarding internal & external metal loss features plus an additional ili run to verify original ili results. After investigation, targa has concluded through process of elimination that the leak was caused by external corrosion due to dc interference. No internal corrosion was found during metallurgical analysis. During routine cathodic surveys on pipeline a 3rd party production company rectifier was found installed with wiring reversed causing pipeline to become anodic and this was corrected promptly. After pipe was removed for repairs holidays in coating were discovered which eventually led to leak in pipeline. To mitigate this from recurring targa has installed remote monitoring units on section of replaced pipeline to monitor cathodic protection in real time. We have also installed 3 magnesium anodes on each side of replaced section of pipeline to prevent corrosion on pipeline. Another mitigation component is that we conducted a close interval survey and had a new ac interference study completed on pipeline to verify no additional threats existed. Additional ili results verified no threats on pipeline exist after replacement pipe was installed based on imp parameters. However, to further mitigate possibility of pipeline corrosion, targa has elected to dig, verify, and repair all anomalies identified by 2nd ili run.
Detailed record list
Report Received Date
2022-07-07 00:00:00
Iyear
2022
Report Number
20220141
Supplemental Number
36982
Report Type
Supplemental Final
Operator Id
39823
Name
Targa Downstream Llc
Operator Street Address
811 Louisiana St. Suite 2100
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2022-06-11 15:10:00
Time Zone
Central
Daylight Savings Ind
Yes
Location Latitude
31.64256
Location Longitude
-101.66996
Commodity Released Type
Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions
Commodity Subtype
Lpg (Liquefied Petroleum Gas) / Ngl (Natural Gas Liquid)
Unintentional Release Bbls
5100
Intentional Release Bbls
4200
Recovered Bbls
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Notification From Public
Incident Identified Datetime
2022-06-11 15:10:00
System Part Involved
Onshore Pipeline, Including Valve Sites
On Off Shore
Onshore
Status When Identified
Normal Operation, Includes Pauses Between Batches And During Maintenance
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2022-06-11 21:18:00
Restart Datetime
2022-06-15 15:30:00
Communication State Fed Ind
No
On Site Datetime
2022-06-11 17:45:00
Confirmed Discovery Datetime
2022-06-11 17:45:00
Nrc Rpt Datetime
2022-06-11 18:11:00
Nrc Rpt Num
1338505
Additional Nrc Report Numbers
1338646
Ignite Ind
No
Upstream Action Taken
Valve Closure
Upstream Valve Close Datetime
2022-06-11 21:18:00
Upstream Valve Type Ind
Remotely Controlled
Downstream Action Taken
Valve Closure
Downstream Vlv Close Datetime
2022-06-11 21:18:00
Downstream Valve Type Ind
Remotely Controlled
Num Pub Evacuated
0
Pipe Fac Name
Grand Prix West
Segment Name
Gateway Lateral 10"
Onshore State Abbreviation
Tx
Onshore Postal Code
79755
Onshore City Name
Midkiff
Onshore County Name
Reagan
Designated Location
Survey Station No.
Designated Name
Gpx-D6
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
72
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Pipe
Pipe Type
Pipe Body
Puddle Weld Ind
No
Pipe Diameter
10
Pipe Wall Thickness
0.25
Pipe Smys
52000
Pipe Specification
Api 5l
Pipe Seam Type
Erw - High Frequency
Pipe Manufacturer
Seah Steel Corp.
Pipe Coating Type
Fusion Bonded Epoxy(Fbe)
Coating Applied Ind
No
Installation Year
2020
Manufactured Year
2018
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Wildlife Impact Ind
No
Soil Contamination
No
Long Term Assessment
No
Remediation Ind
No
Water Contam Ind
No
Could Be Hca
No
Commodity Reached Hca
No
Est Cost Oper Paid
3790
Est Cost Gas Released
351900
Est Cost Prop Damage
65000
Est Cost Emergency
0
Est Cost Environmental
0
Est Cost Other
0
Prpty
420690
Num Persons Hosp Not Ovnght
0
Num Injured Treated By Emt
0
Num Resident Building Affctd
0
Num Business Building Affctd
0
Accident Psig
950
Mop Psig
1440
Mop Cfr Section
Component Design Pressure �195.406(A)(2)
Maop Established Date
2020-06-06 00:00:00
Maop Reversal Flow Ind
No
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction Ind
No
Length Segment Isolated
41565
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
> 20% Smys Regulated Transmission
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
No
Scada Conf Ind
No
Cpm In Place Ind
No
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
There were no alarms or abnormal operations leading up to discovery of leak that would suggest controller error. Additionally, previous ili report anomaly matched exact location of where pinhole was found in pipeline.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
Localized Pitting
Stray Current Corrosion Ind
Yes
Stray Current Type
Direct Current
Stray Current Details
3rd Party Production Company Rectifier Wiring Installed Backwards Causing Pipeline To Become Anodic. Also, Multiple Other Utilities In Vicinity Including: Gas Lines, Gas/oil Wells, Overhead Power/hvac.
Field Exam Basis Ind
Yes
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
2020
Shielding Evident
Yes
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Close Interval Survey Ind
Yes
Other Cp Survey Ind
Yes
Cp Annual Survey Year
2022
Close Interval Survey Year
2022
Other Cp Survey Year
2022
Other Cp Survey Details
A/c Interference Survey
Prior Damage
Yes
Collected Data Ind
Yes
Axial Magnetic Flx Lkg Ind
Yes
Geometry Deformation Ind
Yes
Axial Recent Year
2022
Axial Rcnt Propul Method
Free Swimming
Axial Rcnt Attuned Detect
Metal Loss
Axial Rcnt Atnd Dtct Metal
High Resolution
Geometry Recent Year
2022
Geometry Rcnt Propul Method
Free Swimming
Geometry Rcnt Resolution
High Resolution
Geometrt Rcnt Measur Cups
Inside Ili Cups
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
J***** N****
Preparer Title
Specialist Pipeline Compliance
Preparer Email
J*****@t*************.com
Preparer Telephone
9405779500
Prepared Date
2022-08-16 00:00:00
Local Contact Name
J***** N****
Local Contact Email
J*****@t*************.com
Local Contact Telephone
9405779500
Authorizer Name
J***** N****
Authorizer Telephone
9405779500
Authorizer Title
Specialist Pipeline Compliance
Authorizer Email
J*****@t*************.com
Narrative
At approximately 15:10 targa was contacted by 3rd party of a possible pipeline leak. Personnel were dispatched to site and pipeline control room was notified of possible leak. Targa personnel arrived on-site and found vapors slowly leaking out of ground with an ice sheet along the pipeline right-of-way. Line was verified to be targa's gateway lateral using maps, line locator & ice sheet matched properties of product being transported (hvl). On-site personnel began monitoring area for any unsafe conditions and based on rural location and weather conditions at time of leak there were no threats to public safety. Operations then began process of shutting down pipeline to stop leak. Due to the operational complexity of the system various processes had to take place to take the pipeline out of service safely. During this time on-site personnel continuously monitored leak ensuring area was kept safe. Pipeline was shut in and evacuated of product using nitrogen and pigging for repair and remediation processes to begin. Deformation and metal loss integrity assessed by ili was conducted on 4/7/2022. Final ili report was issued to targa on 6/6/22, 5 days before leak occurred, and contained no immediate repair conditions or src's. There were 60-day and 180-day repair conditions identified in ili report. The features identified were external & internal metal loss attributable to manufacturing related defects. All features found by ili were within a 300-foot section of pipeline, therefore targa elected to replace an entire 300-foot section of pipe to repair all features and to prevent recurrence of possible leak. Additionally, targa has initiated 3rd party investigations regarding internal & external metal loss features plus an additional ili run to verify original ili results. After investigation, targa has concluded through process of elimination that the leak was caused by external corrosion due to dc interference. No internal corrosion was found during metallurgical analysis. During routine cathodic surveys on pipeline a 3rd party production company rectifier was found installed with wiring reversed causing pipeline to become anodic and this was corrected promptly. After pipe was removed for repairs holidays in coating were discovered which eventually led to leak in pipeline. To mitigate this from recurring targa has installed remote monitoring units on section of replaced pipeline to monitor cathodic protection in real time. We have also installed 3 magnesium anodes on each side of replaced section of pipeline to prevent corrosion on pipeline. Another mitigation component is that we conducted a close interval survey and had a new ac interference study completed on pipeline to verify no additional threats existed. Additional ili results verified no threats on pipeline exist after replacement pipe was installed based on imp parameters. However, to further mitigate possibility of pipeline corrosion, targa has elected to dig, verify, and repair all anomalies identified by 2nd ili run.
| Report Received Date | 2022-07-07 00:00:00 |
|---|---|
| Iyear | 2022 |
| Report Number | 20220141 |
| Supplemental Number | 36982 |
| Report Type | Supplemental Final |
| Operator Id | 39823 PHMSA Enforcement |
| Name | Targa Downstream Llc |
| Operator Street Address | 811 Louisiana St. Suite 2100 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2022-06-11 15:10:00 |
| Time Zone | Central |
| Daylight Savings Ind | Yes |
| Location Latitude | 31.64256 Google Maps OpenStreetMap |
| Location Longitude | -101.66996 Google Maps OpenStreetMap |
| Commodity Released Type | Hvl Or Other Flammable Or Toxic Fluid Which Is A Gas At Ambient Conditions |
| Commodity Subtype | Lpg (Liquefied Petroleum Gas) / Ngl (Natural Gas Liquid) |
| Unintentional Release Bbls | 5100 |
| Intentional Release Bbls | 4200 |
| Recovered Bbls | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Notification From Public |
| Incident Identified Datetime | 2022-06-11 15:10:00 |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| On Off Shore | Onshore |
| Status When Identified | Normal Operation, Includes Pauses Between Batches And During Maintenance |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2022-06-11 21:18:00 |
| Restart Datetime | 2022-06-15 15:30:00 |
| Communication State Fed Ind | No |
| On Site Datetime | 2022-06-11 17:45:00 |
| Confirmed Discovery Datetime | 2022-06-11 17:45:00 |
| Nrc Rpt Datetime | 2022-06-11 18:11:00 |
| Nrc Rpt Num | 1338505 NRC Report How to search |
| Additional Nrc Report Numbers | 1338646 |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Upstream Valve Close Datetime | 2022-06-11 21:18:00 |
| Upstream Valve Type Ind | Remotely Controlled |
| Downstream Action Taken | Valve Closure |
| Downstream Vlv Close Datetime | 2022-06-11 21:18:00 |
| Downstream Valve Type Ind | Remotely Controlled |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Grand Prix West |
| Segment Name | Gateway Lateral 10" |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 79755 |
| Onshore City Name | Midkiff |
| Onshore County Name | Reagan |
| Designated Location | Survey Station No. |
| Designated Name | Gpx-D6 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 72 |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Puddle Weld Ind | No |
| Pipe Diameter | 10 |
| Pipe Wall Thickness | 0.25 |
| Pipe Smys | 52000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Erw - High Frequency |
| Pipe Manufacturer | Seah Steel Corp. |
| Pipe Coating Type | Fusion Bonded Epoxy(Fbe) |
| Coating Applied Ind | No |
| Installation Year | 2020 |
| Manufactured Year | 2018 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Wildlife Impact Ind | No |
| Soil Contamination | No |
| Long Term Assessment | No |
| Remediation Ind | No |
| Water Contam Ind | No |
| Could Be Hca | No |
| Commodity Reached Hca | No |
| Est Cost Oper Paid | 3790 |
| Est Cost Gas Released | 351900 |
| Est Cost Prop Damage | 65000 |
| Est Cost Emergency | 0 |
| Est Cost Environmental | 0 |
| Est Cost Other | 0 |
| Prpty | 420690 |
| Num Persons Hosp Not Ovnght | 0 |
| Num Injured Treated By Emt | 0 |
| Num Resident Building Affctd | 0 |
| Num Business Building Affctd | 0 |
| Accident Psig | 950 |
| Mop Psig | 1440 |
| Mop Cfr Section | Component Design Pressure �195.406(A)(2) View CFR 49 §192 |
| Maop Established Date | 2020-06-06 00:00:00 |
| Maop Reversal Flow Ind | No |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction Ind | No |
| Length Segment Isolated | 41565 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | > 20% Smys Regulated Transmission |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | No |
| Scada Conf Ind | No |
| Cpm In Place Ind | No |
| 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 | There were no alarms or abnormal operations leading up to discovery of leak that would suggest controller error. Additionally, previous ili report anomaly matched exact location of where pinhole was found in pipeline. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | Localized Pitting |
| Stray Current Corrosion Ind | Yes |
| Stray Current Type | Direct Current |
| Stray Current Details | 3rd Party Production Company Rectifier Wiring Installed Backwards Causing Pipeline To Become Anodic. Also, Multiple Other Utilities In Vicinity Including: Gas Lines, Gas/oil Wells, Overhead Power/hvac. |
| Field Exam Basis Ind | Yes |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 2020 |
| Shielding Evident | Yes |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Close Interval Survey Ind | Yes |
| Other Cp Survey Ind | Yes |
| Cp Annual Survey Year | 2022 |
| Close Interval Survey Year | 2022 |
| Other Cp Survey Year | 2022 |
| Other Cp Survey Details | A/c Interference Survey |
| Prior Damage | Yes |
| Collected Data Ind | Yes |
| Axial Magnetic Flx Lkg Ind | Yes |
| Geometry Deformation Ind | Yes |
| Axial Recent Year | 2022 |
| Axial Rcnt Propul Method | Free Swimming |
| Axial Rcnt Attuned Detect | Metal Loss |
| Axial Rcnt Atnd Dtct Metal | High Resolution |
| Geometry Recent Year | 2022 |
| Geometry Rcnt Propul Method | Free Swimming |
| Geometry Rcnt Resolution | High Resolution |
| Geometrt Rcnt Measur Cups | Inside Ili Cups |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | J***** N**** |
| Preparer Title | Specialist Pipeline Compliance |
| Preparer Email | J*****@t*************.com |
| Preparer Telephone | 9405779500 |
| Prepared Date | 2022-08-16 00:00:00 |
| Local Contact Name | J***** N**** |
| Local Contact Email | J*****@t*************.com |
| Local Contact Telephone | 9405779500 |
| Authorizer Name | J***** N**** |
| Authorizer Telephone | 9405779500 |
| Authorizer Title | Specialist Pipeline Compliance |
| Authorizer Email | J*****@t*************.com |
| Narrative | At approximately 15:10 targa was contacted by 3rd party of a possible pipeline leak. Personnel were dispatched to site and pipeline control room was notified of possible leak. Targa personnel arrived on-site and found vapors slowly leaking out of ground with an ice sheet along the pipeline right-of-way. Line was verified to be targa's gateway lateral using maps, line locator & ice sheet matched properties of product being transported (hvl). On-site personnel began monitoring area for any unsafe conditions and based on rural location and weather conditions at time of leak there were no threats to public safety. Operations then began process of shutting down pipeline to stop leak. Due to the operational complexity of the system various processes had to take place to take the pipeline out of service safely. During this time on-site personnel continuously monitored leak ensuring area was kept safe. Pipeline was shut in and evacuated of product using nitrogen and pigging for repair and remediation processes to begin. Deformation and metal loss integrity assessed by ili was conducted on 4/7/2022. Final ili report was issued to targa on 6/6/22, 5 days before leak occurred, and contained no immediate repair conditions or src's. There were 60-day and 180-day repair conditions identified in ili report. The features identified were external & internal metal loss attributable to manufacturing related defects. All features found by ili were within a 300-foot section of pipeline, therefore targa elected to replace an entire 300-foot section of pipe to repair all features and to prevent recurrence of possible leak. Additionally, targa has initiated 3rd party investigations regarding internal & external metal loss features plus an additional ili run to verify original ili results. After investigation, targa has concluded through process of elimination that the leak was caused by external corrosion due to dc interference. No internal corrosion was found during metallurgical analysis. During routine cathodic surveys on pipeline a 3rd party production company rectifier was found installed with wiring reversed causing pipeline to become anodic and this was corrected promptly. After pipe was removed for repairs holidays in coating were discovered which eventually led to leak in pipeline. To mitigate this from recurring targa has installed remote monitoring units on section of replaced pipeline to monitor cathodic protection in real time. We have also installed 3 magnesium anodes on each side of replaced section of pipeline to prevent corrosion on pipeline. Another mitigation component is that we conducted a close interval survey and had a new ac interference study completed on pipeline to verify no additional threats existed. Additional ili results verified no threats on pipeline exist after replacement pipe was installed based on imp parameters. However, to further mitigate possibility of pipeline corrosion, targa has elected to dig, verify, and repair all anomalies identified by 2nd ili run. |
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