Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2018-05-10 — TX
Operator
Sunoco Pipeline L.p.
Cause
Corrosion Failure
Commodity
Crude Oil
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$1,120,926
Incident datetime
2018-05-10 16:44
Report number
Location
TX
Narrative
On may 10, 2018 at 16:44, the noble to douglas 8" pipeline was shut down by the houston control center due to cpm (leakwarn) indications. Control center contacted local emergency planning committee to alert of a possible release. Local emergency responders were aware of the release and provided location information. Control center then contacted local operations management and personnel were dispatched to the area. The leak occurred near the intersection of nw 164th st. And north penn ave near edmond, ok, which is approximately 13 miles downstream of the noble pump station. After arrival, operating personnel manually closed valves upstream and downstream of the failure. Upon arriving at the release location at approximately 17:30, local operations management determined at approximately 18:15 that due to the nature of the release, repair and anticipated remediation costs would exceed $50,000. Nrc was then contacted and report 1211819 was issued. On may 11, the required 48 hour update call was placed to nrc. Volume released was updated to 15 bbls and report 1211901 was issued. Control center review of scada data indicates that the release may have begun at approximately 16:04. Leakwarn system was operating at the time but not functional to the console due to routine maintenance beginning at 15:45. Scada indications of a release may have been masked by the startup of a downstream injection point at 15:47. Leakwarn was returned to the console at 16:27. First leakwarn imbalance warning alarm was at 16:39 and the sr imbalance alarm was at 16:42 and reviewed by controller and then line was shutdown at 16:44. Results of the in-field visual analysis indicated that the failure occurred at the 12 o'clock orientation in an area of external corrosion approximately 10" x 1.5". Coating damage and possible mechanical damage were also visible in the failed area. Review of cathodic protection data indicates this area was likely subject to local stray current interference leading to a localized accelerated external corrosion growth rate. The failed section of pipe was then preserved and shipped to det norske veritas USA (dnv), who will perform metallurgical analysis of the failed section of pipe. In 2015, a high density polyethylene liner (hdpe) appropriate for use in crude oil service was installed in this pipeline to prevent degradation of the internal surface of the steel pipe via internal corrosion. To determine that this liner had not been a contributing factor to the failure, a company metallurgical engineer examined the failed section of pipe. This examination concluded that the steel failed at an area of external corrosion and coating damage, which had caused the liner underneath to bulge. As a result, the liner was pierced by the sharp edges of the corroded steel pipe. Repair included replacement of approximately 2,000' of pipe and internal liner. The replacement pipe was hydrostatically tested and a new liner was then installed. After liner installation, the segment of pipe was again hydrostatically tested. Upon repair completion the pipeline was restarted on may 26, with regulatory agency approval. Dnv metallurgical analysis determined that the leak occurred in an area of through wall, external corrosion pits which were aligned with an area of top side mechanical damage, in the form of a gouge. The aligned corrosion pits resulted in a wide through wall flaw. The internal liner bulged prior to the failure and the sharp edges of the corroded pipe tore the liner which ultimately resulted in the leak. Further analysis of cathodic protection data confirmed this area was subject to local stray current interference which caused an accelerated corrosion growth rate at the failure point. Subsequent remedial measures to correct these conditions in the area of the failure have been completed.
Detailed record list
Report Received Date
2018-06-08 00:00:00
Iyear
2018
Report Number
20180168
Supplemental Number
32181
Report Type
Supplemental Final
Operator Id
18718
Name
Sunoco Pipeline L.p.
Operator Street Address
1300 Main Street
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2018-05-10 16:04:00
Location Latitude
35.64222
Location Longitude
-97.5532
Commodity Released Type
Crude Oil
Unintentional Release Bbls
15
Recovered Bbls
10
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Cpm Leak Detection System Or Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Calculations)
Incident Identified Datetime
2018-05-10 16:44:00
System Part Involved
Onshore Pipeline, Including Valve Sites
On Off Shore
Onshore
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2018-05-10 16:44:00
Restart Datetime
2018-05-26 10:22:00
On Site Datetime
2018-05-10 17:30:00
Nrc Rpt Datetime
2018-05-10 19:16:00
Nrc Rpt Num
1211819
Ignite Ind
No
Explode Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Num Pub Evacuated
0
Pipe Fac Name
Noble To Douglas 8"
Segment Name
Noble To Deer Creek
Onshore State Abbreviation
Ok
Onshore Postal Code
73013
Onshore City Name
Edmond
Onshore County Name
Oklahoma
Designated Location
Milepost/valve Station
Designated Name
13.92
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
26
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
8
Pipe Wall Thickness
0.277
Pipe Smys
25000
Pipe Specification
Api 5l
Pipe Seam Type
Lap Welded
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Installation Year
1950
Manufactured Year
1950
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Other
Leak Type Other
Through Wall Corrosion Flaw
Wildlife Impact Ind
No
Soil Contamination
Yes
Long Term Assessment
No
Remediation Ind
Yes
Soil Remed Ind
Yes
Vegetation Remed Ind
Yes
Water Contam Ind
No
Could Be Hca
Yes
Commodity Reached Hca
Yes
High Pop Ind
Yes
High Pop Yes No
Yes
Est Cost Oper Paid
3193535
Est Cost Gas Released
1200
Est Cost Prop Damage
1120926
Est Cost Emergency
307268
Est Cost Environmental
163074
Est Cost Other
0
Prpty
4786003
Accident Psig
375
Mop Psig
640
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction Ind
No
Length Segment Isolated
33257
Internal Inspection Ind
No
Other Inspection Ind
Yes
Internal Inspection Details
Hdpe Internal Liner
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
Yes
Cpm Operating Ind
Yes
Cpm Functional Ind
No
Cpm Detection Ind
Yes
Cpm Conf Ind
Yes
Investigation Status
Yes, specify investigation result(s): (select all that apply)
Invest Schedule Ind
Yes
Invest Other Ind
Yes
Invest Other Ind Details
Live Cpm System Will No Longer Be Temporarily Disabled To Push System Updates. When Updates To The Cpm System Are Required It Will Be Run From The Development Server While The Production System Is Updated.
Employee Drug Test Ind
Yes
Contractor Drug Test Ind
No
Num Employees Tested
1
Num Employees Failed
0
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
Localized Pitting
Galvanic Corrosion Ind
Yes
Stray Current Corrosion Ind
Yes
Field Exam Basis Ind
Yes
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
Unknown
Shielding Evident
Yes
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Close Interval Survey Ind
Yes
Cp Annual Survey Year
2017
Close Interval Survey Year
2017
Prior Damage
Yes
Collected Data Ind
Yes
Axial Magnetic Flx Lkg Ind
Yes
Geometry Deformation Ind
Yes
Axial Recent Year
2013
Geometry Recent Year
2013
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2014
Hydrtst Most Rcnt Pressure
801
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
T*** N*******
Preparer Title
Sr. Manager - Dot Compliance
Preparer Email
T************@e*************.com
Preparer Telephone
713-989-7126
Preparer Fax
877-917-0448
Prepared Date
2019-05-22 00:00:00
Authorizer Name
T*** N*******
Authorizer Telephone
713-989-7126
Authorizer Title
Sr. Manager - Dot Compliance
Authorizer Email
T************@e*************.com
Narrative
On may 10, 2018 at 16:44, the noble to douglas 8" pipeline was shut down by the houston control center due to cpm (leakwarn) indications. Control center contacted local emergency planning committee to alert of a possible release. Local emergency responders were aware of the release and provided location information. Control center then contacted local operations management and personnel were dispatched to the area. The leak occurred near the intersection of nw 164th st. And north penn ave near edmond, ok, which is approximately 13 miles downstream of the noble pump station. After arrival, operating personnel manually closed valves upstream and downstream of the failure. Upon arriving at the release location at approximately 17:30, local operations management determined at approximately 18:15 that due to the nature of the release, repair and anticipated remediation costs would exceed $50,000. Nrc was then contacted and report 1211819 was issued. On may 11, the required 48 hour update call was placed to nrc. Volume released was updated to 15 bbls and report 1211901 was issued. Control center review of scada data indicates that the release may have begun at approximately 16:04. Leakwarn system was operating at the time but not functional to the console due to routine maintenance beginning at 15:45. Scada indications of a release may have been masked by the startup of a downstream injection point at 15:47. Leakwarn was returned to the console at 16:27. First leakwarn imbalance warning alarm was at 16:39 and the sr imbalance alarm was at 16:42 and reviewed by controller and then line was shutdown at 16:44. Results of the in-field visual analysis indicated that the failure occurred at the 12 o'clock orientation in an area of external corrosion approximately 10" x 1.5". Coating damage and possible mechanical damage were also visible in the failed area. Review of cathodic protection data indicates this area was likely subject to local stray current interference leading to a localized accelerated external corrosion growth rate. The failed section of pipe was then preserved and shipped to det norske veritas USA (dnv), who will perform metallurgical analysis of the failed section of pipe. In 2015, a high density polyethylene liner (hdpe) appropriate for use in crude oil service was installed in this pipeline to prevent degradation of the internal surface of the steel pipe via internal corrosion. To determine that this liner had not been a contributing factor to the failure, a company metallurgical engineer examined the failed section of pipe. This examination concluded that the steel failed at an area of external corrosion and coating damage, which had caused the liner underneath to bulge. As a result, the liner was pierced by the sharp edges of the corroded steel pipe. Repair included replacement of approximately 2,000' of pipe and internal liner. The replacement pipe was hydrostatically tested and a new liner was then installed. After liner installation, the segment of pipe was again hydrostatically tested. Upon repair completion the pipeline was restarted on may 26, with regulatory agency approval. Dnv metallurgical analysis determined that the leak occurred in an area of through wall, external corrosion pits which were aligned with an area of top side mechanical damage, in the form of a gouge. The aligned corrosion pits resulted in a wide through wall flaw. The internal liner bulged prior to the failure and the sharp edges of the corroded pipe tore the liner which ultimately resulted in the leak. Further analysis of cathodic protection data confirmed this area was subject to local stray current interference which caused an accelerated corrosion growth rate at the failure point. Subsequent remedial measures to correct these conditions in the area of the failure have been completed.
| Report Received Date | 2018-06-08 00:00:00 |
|---|---|
| Iyear | 2018 |
| Report Number | 20180168 |
| Supplemental Number | 32181 |
| Report Type | Supplemental Final |
| Operator Id | 18718 PHMSA Enforcement |
| Name | Sunoco Pipeline L.p. |
| Operator Street Address | 1300 Main Street |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2018-05-10 16:04:00 |
| Location Latitude | 35.64222 Google Maps OpenStreetMap |
| Location Longitude | -97.5532 Google Maps OpenStreetMap |
| Commodity Released Type | Crude Oil |
| Unintentional Release Bbls | 15 |
| Recovered Bbls | 10 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Cpm Leak Detection System Or Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Calculations) |
| Incident Identified Datetime | 2018-05-10 16:44:00 |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2018-05-10 16:44:00 |
| Restart Datetime | 2018-05-26 10:22:00 |
| On Site Datetime | 2018-05-10 17:30:00 |
| Nrc Rpt Datetime | 2018-05-10 19:16:00 |
| Nrc Rpt Num | 1211819 NRC Report How to search |
| Ignite Ind | No |
| Explode Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Noble To Douglas 8" |
| Segment Name | Noble To Deer Creek |
| Onshore State Abbreviation | Ok |
| Onshore Postal Code | 73013 |
| Onshore City Name | Edmond |
| Onshore County Name | Oklahoma |
| Designated Location | Milepost/valve Station |
| Designated Name | 13.92 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 26 |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 8 |
| Pipe Wall Thickness | 0.277 |
| Pipe Smys | 25000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Lap Welded |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Installation Year | 1950 |
| Manufactured Year | 1950 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Other |
| Leak Type Other | Through Wall Corrosion Flaw |
| Wildlife Impact Ind | No |
| Soil Contamination | Yes |
| Long Term Assessment | No |
| Remediation Ind | Yes |
| Soil Remed Ind | Yes |
| Vegetation Remed Ind | Yes |
| Water Contam Ind | No |
| Could Be Hca | Yes |
| Commodity Reached Hca | Yes |
| High Pop Ind | Yes |
| High Pop Yes No | Yes |
| Est Cost Oper Paid | 3193535 |
| Est Cost Gas Released | 1200 |
| Est Cost Prop Damage | 1120926 |
| Est Cost Emergency | 307268 |
| Est Cost Environmental | 163074 |
| Est Cost Other | 0 |
| Prpty | 4786003 |
| Accident Psig | 375 |
| Mop Psig | 640 |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction Ind | No |
| Length Segment Isolated | 33257 |
| Internal Inspection Ind | No |
| Other Inspection Ind | Yes |
| Internal Inspection Details | Hdpe Internal Liner |
| 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 | Yes |
| Cpm Operating Ind | Yes |
| Cpm Functional Ind | No |
| Cpm Detection Ind | Yes |
| Cpm Conf Ind | Yes |
| Investigation Status | Yes, specify investigation result(s): (select all that apply) |
| Invest Schedule Ind | Yes |
| Invest Other Ind | Yes |
| Invest Other Ind Details | Live Cpm System Will No Longer Be Temporarily Disabled To Push System Updates. When Updates To The Cpm System Are Required It Will Be Run From The Development Server While The Production System Is Updated. |
| Employee Drug Test Ind | Yes |
| Contractor Drug Test Ind | No |
| Num Employees Tested | 1 |
| Num Employees Failed | 0 |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | Localized Pitting |
| Galvanic Corrosion Ind | Yes |
| Stray Current Corrosion Ind | Yes |
| Field Exam Basis Ind | Yes |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | Unknown |
| Shielding Evident | Yes |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Close Interval Survey Ind | Yes |
| Cp Annual Survey Year | 2017 |
| Close Interval Survey Year | 2017 |
| Prior Damage | Yes |
| Collected Data Ind | Yes |
| Axial Magnetic Flx Lkg Ind | Yes |
| Geometry Deformation Ind | Yes |
| Axial Recent Year | 2013 |
| Geometry Recent Year | 2013 |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2014 |
| Hydrtst Most Rcnt Pressure | 801 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | T*** N******* |
| Preparer Title | Sr. Manager - Dot Compliance |
| Preparer Email | T************@e*************.com |
| Preparer Telephone | 713-989-7126 |
| Preparer Fax | 877-917-0448 |
| Prepared Date | 2019-05-22 00:00:00 |
| Authorizer Name | T*** N******* |
| Authorizer Telephone | 713-989-7126 |
| Authorizer Title | Sr. Manager - Dot Compliance |
| Authorizer Email | T************@e*************.com |
| Narrative | On may 10, 2018 at 16:44, the noble to douglas 8" pipeline was shut down by the houston control center due to cpm (leakwarn) indications. Control center contacted local emergency planning committee to alert of a possible release. Local emergency responders were aware of the release and provided location information. Control center then contacted local operations management and personnel were dispatched to the area. The leak occurred near the intersection of nw 164th st. And north penn ave near edmond, ok, which is approximately 13 miles downstream of the noble pump station. After arrival, operating personnel manually closed valves upstream and downstream of the failure. Upon arriving at the release location at approximately 17:30, local operations management determined at approximately 18:15 that due to the nature of the release, repair and anticipated remediation costs would exceed $50,000. Nrc was then contacted and report 1211819 was issued. On may 11, the required 48 hour update call was placed to nrc. Volume released was updated to 15 bbls and report 1211901 was issued. Control center review of scada data indicates that the release may have begun at approximately 16:04. Leakwarn system was operating at the time but not functional to the console due to routine maintenance beginning at 15:45. Scada indications of a release may have been masked by the startup of a downstream injection point at 15:47. Leakwarn was returned to the console at 16:27. First leakwarn imbalance warning alarm was at 16:39 and the sr imbalance alarm was at 16:42 and reviewed by controller and then line was shutdown at 16:44. Results of the in-field visual analysis indicated that the failure occurred at the 12 o'clock orientation in an area of external corrosion approximately 10" x 1.5". Coating damage and possible mechanical damage were also visible in the failed area. Review of cathodic protection data indicates this area was likely subject to local stray current interference leading to a localized accelerated external corrosion growth rate. The failed section of pipe was then preserved and shipped to det norske veritas USA (dnv), who will perform metallurgical analysis of the failed section of pipe. In 2015, a high density polyethylene liner (hdpe) appropriate for use in crude oil service was installed in this pipeline to prevent degradation of the internal surface of the steel pipe via internal corrosion. To determine that this liner had not been a contributing factor to the failure, a company metallurgical engineer examined the failed section of pipe. This examination concluded that the steel failed at an area of external corrosion and coating damage, which had caused the liner underneath to bulge. As a result, the liner was pierced by the sharp edges of the corroded steel pipe. Repair included replacement of approximately 2,000' of pipe and internal liner. The replacement pipe was hydrostatically tested and a new liner was then installed. After liner installation, the segment of pipe was again hydrostatically tested. Upon repair completion the pipeline was restarted on may 26, with regulatory agency approval. Dnv metallurgical analysis determined that the leak occurred in an area of through wall, external corrosion pits which were aligned with an area of top side mechanical damage, in the form of a gouge. The aligned corrosion pits resulted in a wide through wall flaw. The internal liner bulged prior to the failure and the sharp edges of the corroded pipe tore the liner which ultimately resulted in the leak. Further analysis of cathodic protection data confirmed this area was subject to local stray current interference which caused an accelerated corrosion growth rate at the failure point. Subsequent remedial measures to correct these conditions in the area of the failure have been completed. |
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