Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2019-08-29 — TX
Operator
Motiva Enterprise Llc
Cause
Material Failure Of Pipe Or Weld
Commodity
Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$88,700
Incident datetime
2019-08-29 16:30
Report number
Location
TX
Narrative
Operators found a small amount of dark oil on the ground at the 7th street tank farm. A maintenance crew began excavating. At ~16:30 (thursday, 8/29), following stain, crew noticed a small amount of oil bubbling every few seconds ~30 feet away from the initial finding, close to where the 16" dock line runs underground. To prevent the leak from potentially worsening, the crew stopped digging and plans to flush (with light-cycle gas oil) and depressure the line were initiated. Excavation continued friday morning. ~30 feet of the line was exposed in different areas, but no obvious leak source was identified. With a viable backup line available, stopped digging for the weekend and initiated a plan to flush the line clear with firewater saturday morning. On tuesday (3 sept) green dye was injected and the line pressured-up to 50 psig. A crack in a circumferential weld of a 45-degree elbow was eventually identified as the leak location. Immediate mitigation plan was to make a temporary repair by installing an engineered bolted enclosure due to the plan to assess the entire pipeline using ili technology scheduled for 2020. Permanent repair by replacing the failed section was planned post ili activities. However, the engineered bolted enclosure would not seal. Therefore, ~10 linear feet of piping and (2) 45-degree elbows were removed and replaced. All replaced piping and fittings were sand blasted and re-coated using sp-2888 (epoxy-urethane coating). After all repairs were made, a hydrotest was performed on 100% of the pipeline. The following nondestructive examinations were also performed: a. 100% visual analysis b. 100% radiographic testing c. 10% dye penetrant testing pei engineer and pei corrosion and materials specialist developed a plan to determine the cause of the failure of the piping. The plan was to receive the failed section of the pipe, take as-received photos, blast the failed section (internal and external), perform visual analysis and dye penetrant examination in the area of the leak location. After visual analysis, dye penetrant testing was performed to determine the extent of cracking in the leak location as well as similar locations in the area of the circumferential weld. Testing indicated the crack was isolated to the area of the leak location. No other cracking was found. It was observed that there was a defective weld in the area of the leak location resulting in a stress riser from which a longitudinal crack propagated. The longitudinal crack propagated due to circumferential stress that may have been caused by one or more of the following causes: a. Bending stress due to misalignment. B. Out-of-roundness exhibited by significant high-low. C. Hoop stress generated by normal operating pressure. To ensure the integrity of the 16" dock line, motiva has the following current plan in place: 1. Ili (inline inspection) in 2020. 2. Perform hydrostatic test in conjunction with ili. 3. Perform integrity risk assessments every 5 years. 4. Perform atmospheric corrosion inspections every 3 years. 5. Cathodic protection monitored bi-monthly rectifier test. 6. Cathodic protection annual potential surveys.
Detailed record list
Report Received Date
2019-09-25 00:00:00
Iyear
2019
Report Number
20190298
Supplemental Number
32922
Report Type
Supplemental Final
Operator Id
30777
Name
Motiva Enterprise Llc
Operator Street Address
One Allen Center 500 Dallas Street
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2019-08-29 16:30:00
Location Latitude
29.850926
Location Longitude
-93.956001
Commodity Released Type
Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions
Commodity Subtype
Diesel, Fuel Oil, Kerosene, Jet Fuel
Unintentional Release Bbls
0.17
Recovered Bbls
0.17
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
Incident Identified Datetime
2019-08-29 16:30:00
System Part Involved
Onshore Pipeline, Including Valve Sites
On Off Shore
Onshore
Shutdown Due Accident Ind
No
Shutdown Explain
The Line Was Not In Operation At The Time Of Leak Discovery
On Site Datetime
2019-08-29 17:00:00
Nrc Rpt Datetime
2019-08-29 18:14:00
Nrc Rpt Num
1256807
Ignite Ind
No
Explode Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Num Pub Evacuated
0
Pipe Fac Name
16" Dl, National Extension
Segment Name
Dockline 26, 7th Street
Onshore State Abbreviation
Tx
Onshore Postal Code
77641-0712
Onshore City Name
Port Arthur
Onshore County Name
Jefferson
Designated Location
Survey Station No.
Designated Name
7th Street
Federal
No
Location Type
Totally Contained On Operator-Controlled Property
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
84
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Weld, Including Heat-Affected Zone
Pipe Diameter
16
Pipe Wall Thickness
0.25
Pipe Smys
36000
Pipe Specification
A-53 Grade B
Pipe Seam Type
Seamless
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Weld Subtype
Pipe Girth Weld
Installation Year
Unknown
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Wildlife Impact Ind
No
Soil Contamination
Yes
Long Term Assessment
No
Remediation Ind
Yes
Surface Water Remed Ind
Yes
Soil Remed Ind
Yes
Vegetation Remed Ind
Yes
Water Contam Ind
No
Could Be Hca
Yes
Commodity Reached Hca
Yes
Other Pop Ind
Yes
Other Pop Yes No
Yes
Est Cost Oper Paid
0
Est Cost Gas Released
0
Est Cost Prop Damage
88700
Est Cost Emergency
10000
Est Cost Environmental
10000
Est Cost Other
0
Prpty
108700
Accident Psig
120
Mop Psig
250
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction Ind
No
Length Segment Isolated
6815
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
< 20% Smys Regulated Transmission
Scada In Place Ind
No
Cpm In Place Ind
No
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
Material Failure Of Pipe Or Weld
Cause Details
Design-, Construction-, Installation-, Or Fabrication-Related
Field Exam Ind
Yes
Metallurgical Ind
Yes
Failure Type
Design-, Construction-, Installation-, Or Fabrication-Related
Mechanical Stress
Yes
Additional Lack Fusion Ind
Yes
Pwf Addl Misalignment Ind
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2017
Hydrtst Most Rcnt Pressure
425
Direct Asmnt Conducted
Yes, But The Point Of The Accident Was Not Identified As A Dig Site
Direct Asmnt Pnt Not Idntf Yr
2018
Non Destructive Exam Ind
No
Preparer Name
C****** R*************
Preparer Title
Dot Compliance Specialist
Preparer Email
C*********************@m*****.com
Preparer Telephone
409-828-1908
Prepared Date
2019-11-12 00:00:00
Authorizer Name
H**** I*****
Authorizer Telephone
832-452-9948
Authorizer Title
Dot Compliance Manager
Authorizer Email
H***********@m*****.com
Narrative
Operators found a small amount of dark oil on the ground at the 7th street tank farm. A maintenance crew began excavating. At ~16:30 (thursday, 8/29), following stain, crew noticed a small amount of oil bubbling every few seconds ~30 feet away from the initial finding, close to where the 16" dock line runs underground. To prevent the leak from potentially worsening, the crew stopped digging and plans to flush (with light-cycle gas oil) and depressure the line were initiated. Excavation continued friday morning. ~30 feet of the line was exposed in different areas, but no obvious leak source was identified. With a viable backup line available, stopped digging for the weekend and initiated a plan to flush the line clear with firewater saturday morning. On tuesday (3 sept) green dye was injected and the line pressured-up to 50 psig. A crack in a circumferential weld of a 45-degree elbow was eventually identified as the leak location. Immediate mitigation plan was to make a temporary repair by installing an engineered bolted enclosure due to the plan to assess the entire pipeline using ili technology scheduled for 2020. Permanent repair by replacing the failed section was planned post ili activities. However, the engineered bolted enclosure would not seal. Therefore, ~10 linear feet of piping and (2) 45-degree elbows were removed and replaced. All replaced piping and fittings were sand blasted and re-coated using sp-2888 (epoxy-urethane coating). After all repairs were made, a hydrotest was performed on 100% of the pipeline. The following nondestructive examinations were also performed: a. 100% visual analysis b. 100% radiographic testing c. 10% dye penetrant testing pei engineer and pei corrosion and materials specialist developed a plan to determine the cause of the failure of the piping. The plan was to receive the failed section of the pipe, take as-received photos, blast the failed section (internal and external), perform visual analysis and dye penetrant examination in the area of the leak location. After visual analysis, dye penetrant testing was performed to determine the extent of cracking in the leak location as well as similar locations in the area of the circumferential weld. Testing indicated the crack was isolated to the area of the leak location. No other cracking was found. It was observed that there was a defective weld in the area of the leak location resulting in a stress riser from which a longitudinal crack propagated. The longitudinal crack propagated due to circumferential stress that may have been caused by one or more of the following causes: a. Bending stress due to misalignment. B. Out-of-roundness exhibited by significant high-low. C. Hoop stress generated by normal operating pressure. To ensure the integrity of the 16" dock line, motiva has the following current plan in place: 1. Ili (inline inspection) in 2020. 2. Perform hydrostatic test in conjunction with ili. 3. Perform integrity risk assessments every 5 years. 4. Perform atmospheric corrosion inspections every 3 years. 5. Cathodic protection monitored bi-monthly rectifier test. 6. Cathodic protection annual potential surveys.
| Report Received Date | 2019-09-25 00:00:00 |
|---|---|
| Iyear | 2019 |
| Report Number | 20190298 |
| Supplemental Number | 32922 |
| Report Type | Supplemental Final |
| Operator Id | 30777 PHMSA Enforcement |
| Name | Motiva Enterprise Llc |
| Operator Street Address | One Allen Center 500 Dallas Street |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2019-08-29 16:30:00 |
| Location Latitude | 29.850926 Google Maps OpenStreetMap |
| Location Longitude | -93.956001 Google Maps OpenStreetMap |
| Commodity Released Type | Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions |
| Commodity Subtype | Diesel, Fuel Oil, Kerosene, Jet Fuel |
| Unintentional Release Bbls | 0.17 |
| Recovered Bbls | 0.17 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| Incident Identified Datetime | 2019-08-29 16:30:00 |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | No |
| Shutdown Explain | The Line Was Not In Operation At The Time Of Leak Discovery |
| On Site Datetime | 2019-08-29 17:00:00 |
| Nrc Rpt Datetime | 2019-08-29 18:14:00 |
| Nrc Rpt Num | 1256807 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 | 16" Dl, National Extension |
| Segment Name | Dockline 26, 7th Street |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 77641-0712 |
| Onshore City Name | Port Arthur |
| Onshore County Name | Jefferson |
| Designated Location | Survey Station No. |
| Designated Name | 7th Street |
| Federal | No |
| Location Type | Totally Contained On Operator-Controlled Property |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 84 |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Weld, Including Heat-Affected Zone |
| Pipe Diameter | 16 |
| Pipe Wall Thickness | 0.25 |
| Pipe Smys | 36000 |
| Pipe Specification | A-53 Grade B |
| Pipe Seam Type | Seamless |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Weld Subtype | Pipe Girth Weld |
| Installation Year | Unknown |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Wildlife Impact Ind | No |
| Soil Contamination | Yes |
| Long Term Assessment | No |
| Remediation Ind | Yes |
| Surface Water Remed Ind | Yes |
| Soil Remed Ind | Yes |
| Vegetation Remed Ind | Yes |
| Water Contam Ind | No |
| Could Be Hca | Yes |
| Commodity Reached Hca | Yes |
| Other Pop Ind | Yes |
| Other Pop Yes No | Yes |
| Est Cost Oper Paid | 0 |
| Est Cost Gas Released | 0 |
| Est Cost Prop Damage | 88700 |
| Est Cost Emergency | 10000 |
| Est Cost Environmental | 10000 |
| Est Cost Other | 0 |
| Prpty | 108700 |
| Accident Psig | 120 |
| Mop Psig | 250 |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction Ind | No |
| Length Segment Isolated | 6815 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | < 20% Smys Regulated Transmission |
| Scada In Place Ind | No |
| Cpm In Place Ind | No |
| 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 | Material Failure Of Pipe Or Weld |
| Cause Details | Design-, Construction-, Installation-, Or Fabrication-Related |
| Field Exam Ind | Yes |
| Metallurgical Ind | Yes |
| Failure Type | Design-, Construction-, Installation-, Or Fabrication-Related |
| Mechanical Stress | Yes |
| Additional Lack Fusion Ind | Yes |
| Pwf Addl Misalignment Ind | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2017 |
| Hydrtst Most Rcnt Pressure | 425 |
| Direct Asmnt Conducted | Yes, But The Point Of The Accident Was Not Identified As A Dig Site |
| Direct Asmnt Pnt Not Idntf Yr | 2018 |
| Non Destructive Exam Ind | No |
| Preparer Name | C****** R************* |
| Preparer Title | Dot Compliance Specialist |
| Preparer Email | C*********************@m*****.com |
| Preparer Telephone | 409-828-1908 |
| Prepared Date | 2019-11-12 00:00:00 |
| Authorizer Name | H**** I***** |
| Authorizer Telephone | 832-452-9948 |
| Authorizer Title | Dot Compliance Manager |
| Authorizer Email | H***********@m*****.com |
| Narrative | Operators found a small amount of dark oil on the ground at the 7th street tank farm. A maintenance crew began excavating. At ~16:30 (thursday, 8/29), following stain, crew noticed a small amount of oil bubbling every few seconds ~30 feet away from the initial finding, close to where the 16" dock line runs underground. To prevent the leak from potentially worsening, the crew stopped digging and plans to flush (with light-cycle gas oil) and depressure the line were initiated. Excavation continued friday morning. ~30 feet of the line was exposed in different areas, but no obvious leak source was identified. With a viable backup line available, stopped digging for the weekend and initiated a plan to flush the line clear with firewater saturday morning. On tuesday (3 sept) green dye was injected and the line pressured-up to 50 psig. A crack in a circumferential weld of a 45-degree elbow was eventually identified as the leak location. Immediate mitigation plan was to make a temporary repair by installing an engineered bolted enclosure due to the plan to assess the entire pipeline using ili technology scheduled for 2020. Permanent repair by replacing the failed section was planned post ili activities. However, the engineered bolted enclosure would not seal. Therefore, ~10 linear feet of piping and (2) 45-degree elbows were removed and replaced. All replaced piping and fittings were sand blasted and re-coated using sp-2888 (epoxy-urethane coating). After all repairs were made, a hydrotest was performed on 100% of the pipeline. The following nondestructive examinations were also performed: a. 100% visual analysis b. 100% radiographic testing c. 10% dye penetrant testing pei engineer and pei corrosion and materials specialist developed a plan to determine the cause of the failure of the piping. The plan was to receive the failed section of the pipe, take as-received photos, blast the failed section (internal and external), perform visual analysis and dye penetrant examination in the area of the leak location. After visual analysis, dye penetrant testing was performed to determine the extent of cracking in the leak location as well as similar locations in the area of the circumferential weld. Testing indicated the crack was isolated to the area of the leak location. No other cracking was found. It was observed that there was a defective weld in the area of the leak location resulting in a stress riser from which a longitudinal crack propagated. The longitudinal crack propagated due to circumferential stress that may have been caused by one or more of the following causes: a. Bending stress due to misalignment. B. Out-of-roundness exhibited by significant high-low. C. Hoop stress generated by normal operating pressure. To ensure the integrity of the 16" dock line, motiva has the following current plan in place: 1. Ili (inline inspection) in 2020. 2. Perform hydrostatic test in conjunction with ili. 3. Perform integrity risk assessments every 5 years. 4. Perform atmospheric corrosion inspections every 3 years. 5. Cathodic protection monitored bi-monthly rectifier test. 6. Cathodic protection annual potential surveys. |
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