Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2016-08-09 — TX
Operator
Dcp Midstream
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)
$325,000
Incident datetime
2016-08-09 13:30
Report number
Location
TX
Narrative
On 8/9 at approximately 13:30 an ngl technician completed an internal leak report on red bluff lateral at the pecos river, based on a suspected leak found by aerial patrol using a flir camera. The ngl technician immediately called the houston control center to shut down the red bluff lateral and the operations team was also notified. Notifications were made to the nrc and txrrc. The operation team then tried to determine the exact location of the leak. After thoroughly investigating, the leak was identified. Booms were later deployed and water samples were also taken as the team began efforts to replace the leaking pipeline and mitigate the affected area. The bore section of the pecos river was removed, replaced with a new bore section and a total of approximately 3232 feet was hydrosatically tested including the new bore. A sample of the removed pipe was sent to a 3rd party engineering firm to determine root cause. While waiting for the report dcp has initiated additional corrosion mitigation efforts. The draft report received from the third party engineering firm indicated the root cause of failure was due to stray current corrosion (ac and dc induced corrosion). Locations were identified along the pipeline segment that potentially had similar conditions to the pecos river crossing, focusing on foreign line crossings, road and river/stream crossings and ac power corridors as areas of potential concern. Dcp midstream completed a total of 31 excavations, none of which revealed any pressure reducing anomalies. Field investigation of the anomalies indicated that only recoating was required, however, dcp midstream did decide to utilize a composite wrap on one (1) of the anomalies. Dcp returned to pipeline to service on 8/26/2016 at a 20% pressure reduction while additional mitigative measures were taken. Dcp midstream implemented the following measures which include the installation of a new ground bed near the pecos river, bonds with select adjacent pipelines as well as the installation of zinc ribbons and decouplers in areas deemed at higher risk from ac stray current. Additional measures to be implemented include conducting a full pipeline close interval and dcvg survey and the installation of one new remote monitoring test station for once per week readings (ac/dc) near the pecos river. Dcp ran a high-resolution mfl ili tool to verify and validate the integrity of the pipeline. The preliminary results determined there were no anomalies satisfying the "immediate condition" criteria outlined in 49 cfr 195.452(h). The six (6) deepest metal loss anomalies were provided by the ili vendor. Dcp selected the six (6) worst anomalies to be excavated to validate the tool run but the safe pressure calculations on the identified anomalies were well above mop. One of the excavated anomalies was found to have a pinhole leak after excavation. Stopples were installed and the anomaly was cut out. Two other anomalies were repaired with type b sleeves, one anomaly was repaired with a composite wrap, and the other anomalies were recoated. The pipeline was returned to full service on 10/12/2016
Detailed record list
Report Received Date
2016-09-08 00:00:00
Iyear
2016
Report Number
20160285
Supplemental Number
21812
Report Type
Supplemental Final
Operator Id
31130
Name
Dcp Midstream
Operator Street Address
2331 Citywest Blvd. Hq-08-S812-02
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77042
Local Datetime
2016-08-09 13:30:00
Location Latitude
31.79952
Location Longitude
-103.80908
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
203
Intentional Release Bbls
2379
Recovered Bbls
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Air Patrol
Operator Type
Contractor Working For The Operator
Incident Identified Datetime
2016-08-09 13:30:00
System Part Involved
Onshore Pipeline, Including Valve Sites
On Off Shore
Onshore
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2016-08-09 13:49:00
Restart Datetime
2016-08-24 23:00:00
On Site Datetime
2016-08-09 16:30:00
Nrc Rpt Datetime
2016-08-09 15:10:00
Nrc Rpt Num
1155742
Ignite Ind
No
Explode Ind
No
Upstream Valve Type Ind
Remotely Controlled
Downstream Valve Type Ind
Remotely Controlled
Num Pub Evacuated
0
Pipe Fac Name
Red Bluff Lateral
Segment Name
Rb-1
Onshore State Abbreviation
Tx
Onshore Postal Code
79770
Onshore City Name
Orla
Onshore County Name
Loving
Designated Location
Survey Station No.
Designated Name
420+00
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
720
Crossing
Yes
Water Crossing Ind
Yes
Water Type
Uncased
Water Name
Pecos River
Water Depth
2
Water Subtype
Shoreline/bank Crossing
Pipe Facility Type
Intrastate
Item Involved
Weld, Including Heat-Affected Zone
Pipe Diameter
12.75
Pipe Wall Thickness
0.375
Pipe Smys
60000
Pipe Specification
Api 5l
Pipe Seam Type
Erw - High Frequency
Pipe Manufacturer
Northwest Pipe
Pipe Coating Type
Field Applied Epoxy
Weld Subtype
Pipe Girth Weld
Installation Year
2015
Manufactured Year
2014
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Wildlife Impact Ind
No
Soil Contamination
No
Long Term Assessment
Yes
Remediation Ind
No
Water Contam Ind
No
Could Be Hca
No
Commodity Reached Hca
No
Est Cost Oper Paid
0
Est Cost Gas Released
51640
Est Cost Prop Damage
325000
Est Cost Emergency
0
Est Cost Environmental
5000
Est Cost Other
0
Prpty
381640
Accident Psig
970
Mop Psig
1440
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction Ind
No
Length Segment Isolated
65736
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
Yes
Cpm In Place Ind
Yes
Cpm Operating Ind
Yes
Cpm Functional Ind
Yes
Cpm Detection Ind
No
Cpm Conf Ind
Yes
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 controller responded appropriately and in a timely manner.
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
Field Exam Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
Unknown
Shielding Evident
Yes
Cathodic Survey Type
No
Prior Damage
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
T**** S******
Preparer Title
Pipeline Compliance And Integrity Specialist
Preparer Email
T*******@d***********.com
Preparer Telephone
713-268-7447
Prepared Date
2016-11-02 00:00:00
Authorizer Name
B****** P*****
Authorizer Telephone
7132687400
Authorizer Title
Director Ngl Pipeline Integrity And Compliance
Authorizer Email
B*******@d***********.com
Narrative
On 8/9 at approximately 13:30 an ngl technician completed an internal leak report on red bluff lateral at the pecos river, based on a suspected leak found by aerial patrol using a flir camera. The ngl technician immediately called the houston control center to shut down the red bluff lateral and the operations team was also notified. Notifications were made to the nrc and txrrc. The operation team then tried to determine the exact location of the leak. After thoroughly investigating, the leak was identified. Booms were later deployed and water samples were also taken as the team began efforts to replace the leaking pipeline and mitigate the affected area. The bore section of the pecos river was removed, replaced with a new bore section and a total of approximately 3232 feet was hydrosatically tested including the new bore. A sample of the removed pipe was sent to a 3rd party engineering firm to determine root cause. While waiting for the report dcp has initiated additional corrosion mitigation efforts. The draft report received from the third party engineering firm indicated the root cause of failure was due to stray current corrosion (ac and dc induced corrosion). Locations were identified along the pipeline segment that potentially had similar conditions to the pecos river crossing, focusing on foreign line crossings, road and river/stream crossings and ac power corridors as areas of potential concern. Dcp midstream completed a total of 31 excavations, none of which revealed any pressure reducing anomalies. Field investigation of the anomalies indicated that only recoating was required, however, dcp midstream did decide to utilize a composite wrap on one (1) of the anomalies. Dcp returned to pipeline to service on 8/26/2016 at a 20% pressure reduction while additional mitigative measures were taken. Dcp midstream implemented the following measures which include the installation of a new ground bed near the pecos river, bonds with select adjacent pipelines as well as the installation of zinc ribbons and decouplers in areas deemed at higher risk from ac stray current. Additional measures to be implemented include conducting a full pipeline close interval and dcvg survey and the installation of one new remote monitoring test station for once per week readings (ac/dc) near the pecos river. Dcp ran a high-resolution mfl ili tool to verify and validate the integrity of the pipeline. The preliminary results determined there were no anomalies satisfying the "immediate condition" criteria outlined in 49 cfr 195.452(h). The six (6) deepest metal loss anomalies were provided by the ili vendor. Dcp selected the six (6) worst anomalies to be excavated to validate the tool run but the safe pressure calculations on the identified anomalies were well above mop. One of the excavated anomalies was found to have a pinhole leak after excavation. Stopples were installed and the anomaly was cut out. Two other anomalies were repaired with type b sleeves, one anomaly was repaired with a composite wrap, and the other anomalies were recoated. The pipeline was returned to full service on 10/12/2016
| Report Received Date | 2016-09-08 00:00:00 |
|---|---|
| Iyear | 2016 |
| Report Number | 20160285 |
| Supplemental Number | 21812 |
| Report Type | Supplemental Final |
| Operator Id | 31130 PHMSA Enforcement |
| Name | Dcp Midstream |
| Operator Street Address | 2331 Citywest Blvd. Hq-08-S812-02 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77042 |
| Local Datetime | 2016-08-09 13:30:00 |
| Location Latitude | 31.79952 Google Maps OpenStreetMap |
| Location Longitude | -103.80908 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 | 203 |
| Intentional Release Bbls | 2379 |
| Recovered Bbls | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Air Patrol |
| Operator Type | Contractor Working For The Operator |
| Incident Identified Datetime | 2016-08-09 13:30:00 |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2016-08-09 13:49:00 |
| Restart Datetime | 2016-08-24 23:00:00 |
| On Site Datetime | 2016-08-09 16:30:00 |
| Nrc Rpt Datetime | 2016-08-09 15:10:00 |
| Nrc Rpt Num | 1155742 NRC Report How to search |
| Ignite Ind | No |
| Explode Ind | No |
| Upstream Valve Type Ind | Remotely Controlled |
| Downstream Valve Type Ind | Remotely Controlled |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Red Bluff Lateral |
| Segment Name | Rb-1 |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 79770 |
| Onshore City Name | Orla |
| Onshore County Name | Loving |
| Designated Location | Survey Station No. |
| Designated Name | 420+00 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 720 |
| Crossing | Yes |
| Water Crossing Ind | Yes |
| Water Type | Uncased |
| Water Name | Pecos River |
| Water Depth | 2 |
| Water Subtype | Shoreline/bank Crossing |
| Pipe Facility Type | Intrastate |
| Item Involved | Weld, Including Heat-Affected Zone |
| Pipe Diameter | 12.75 |
| Pipe Wall Thickness | 0.375 |
| Pipe Smys | 60000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Erw - High Frequency |
| Pipe Manufacturer | Northwest Pipe |
| Pipe Coating Type | Field Applied Epoxy |
| Weld Subtype | Pipe Girth Weld |
| Installation Year | 2015 |
| Manufactured Year | 2014 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Wildlife Impact Ind | No |
| Soil Contamination | No |
| Long Term Assessment | Yes |
| Remediation Ind | No |
| Water Contam Ind | No |
| Could Be Hca | No |
| Commodity Reached Hca | No |
| Est Cost Oper Paid | 0 |
| Est Cost Gas Released | 51640 |
| Est Cost Prop Damage | 325000 |
| Est Cost Emergency | 0 |
| Est Cost Environmental | 5000 |
| Est Cost Other | 0 |
| Prpty | 381640 |
| Accident Psig | 970 |
| Mop Psig | 1440 |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction Ind | No |
| Length Segment Isolated | 65736 |
| 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 | Yes |
| Cpm In Place Ind | Yes |
| Cpm Operating Ind | Yes |
| Cpm Functional Ind | Yes |
| Cpm Detection Ind | No |
| Cpm Conf Ind | Yes |
| 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 controller responded appropriately and in a timely manner. |
| 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 |
| Field Exam Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | Unknown |
| Shielding Evident | Yes |
| Cathodic Survey Type | No |
| Prior Damage | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | T**** S****** |
| Preparer Title | Pipeline Compliance And Integrity Specialist |
| Preparer Email | T*******@d***********.com |
| Preparer Telephone | 713-268-7447 |
| Prepared Date | 2016-11-02 00:00:00 |
| Authorizer Name | B****** P***** |
| Authorizer Telephone | 7132687400 |
| Authorizer Title | Director Ngl Pipeline Integrity And Compliance |
| Authorizer Email | B*******@d***********.com |
| Narrative | On 8/9 at approximately 13:30 an ngl technician completed an internal leak report on red bluff lateral at the pecos river, based on a suspected leak found by aerial patrol using a flir camera. The ngl technician immediately called the houston control center to shut down the red bluff lateral and the operations team was also notified. Notifications were made to the nrc and txrrc. The operation team then tried to determine the exact location of the leak. After thoroughly investigating, the leak was identified. Booms were later deployed and water samples were also taken as the team began efforts to replace the leaking pipeline and mitigate the affected area. The bore section of the pecos river was removed, replaced with a new bore section and a total of approximately 3232 feet was hydrosatically tested including the new bore. A sample of the removed pipe was sent to a 3rd party engineering firm to determine root cause. While waiting for the report dcp has initiated additional corrosion mitigation efforts. The draft report received from the third party engineering firm indicated the root cause of failure was due to stray current corrosion (ac and dc induced corrosion). Locations were identified along the pipeline segment that potentially had similar conditions to the pecos river crossing, focusing on foreign line crossings, road and river/stream crossings and ac power corridors as areas of potential concern. Dcp midstream completed a total of 31 excavations, none of which revealed any pressure reducing anomalies. Field investigation of the anomalies indicated that only recoating was required, however, dcp midstream did decide to utilize a composite wrap on one (1) of the anomalies. Dcp returned to pipeline to service on 8/26/2016 at a 20% pressure reduction while additional mitigative measures were taken. Dcp midstream implemented the following measures which include the installation of a new ground bed near the pecos river, bonds with select adjacent pipelines as well as the installation of zinc ribbons and decouplers in areas deemed at higher risk from ac stray current. Additional measures to be implemented include conducting a full pipeline close interval and dcvg survey and the installation of one new remote monitoring test station for once per week readings (ac/dc) near the pecos river. Dcp ran a high-resolution mfl ili tool to verify and validate the integrity of the pipeline. The preliminary results determined there were no anomalies satisfying the "immediate condition" criteria outlined in 49 cfr 195.452(h). The six (6) deepest metal loss anomalies were provided by the ili vendor. Dcp selected the six (6) worst anomalies to be excavated to validate the tool run but the safe pressure calculations on the identified anomalies were well above mop. One of the excavated anomalies was found to have a pinhole leak after excavation. Stopples were installed and the anomaly was cut out. Two other anomalies were repaired with type b sleeves, one anomaly was repaired with a composite wrap, and the other anomalies were recoated. The pipeline was returned to full service on 10/12/2016 |
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