Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2020-11-23 — TX
Operator
Centurion Pipeline L.p.
Cause
Corrosion Failure
Commodity
Crude Oil
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$37,175
Incident datetime
2020-11-23 12:40
Report number
Location
TX
Narrative
On november 23, 2020, at approximately 12:40 cst, a centurion pipeline l.P. (cpl) employee discovered a leak in cpl's midland station near midland, texas in midland county, texas. Cpl determined the source of the leak to be station piping and promptly isolated the leak. However, one (1) barrel of crude oil was released. The contaminated soil was remediated on site. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to the texas railroad commission, office of pipeline safety at 1320 cst on november 23, 2020, and was issued incident number 2297 in reference to the incident. At the time of this writing, the repair of the station piping is scheduled and the root cause failure analysis will be conducted pending the removal of the damaged piping segment. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and costs associated with repairing the station piping will be submitted via supplemental report(s). Supplemental filed on 03/10/2021: updates include part a-14b; part c-6; part d-8c, 8d, 8e and 8g; part e-5f and 7; and part g. During the root cause failure analysis, cpl determined under-deposit corrosion caused the failure, which resulted from multiple contributing factors. Previously stagnant conditions caused water and solids to deposit near a girth weld on the bottom of a low point in the station piping, and a corrosion cell formed. The corrosion rate increased due to a galvanic couple between the iron sulfide deposit and the steel pipe, which was further exacerbated by a galvanic couple between two different ages of pipe. The combination of the iron sulfide deposit and a paraffin deposit prevented the corrosion mitigation chemicals from reaching the steel surface and reduced their effectiveness. Cpl replaced the entire segment containing the low point and removed the two different ages of pipe. Additionally, cpl will flush and treat the new segment of piping with corrosion mitigation chemicals if a period of no flow exists longer than 90 days. Cpl believes eliminating the contributing factors will prevent similar accidents from occurring.
Detailed record list
Report Received Date
2020-12-21 00:00:00
Iyear
2020
Report Number
20200337
Supplemental Number
34975
Report Type
Supplemental Final
Operator Id
31888
Name
Centurion Pipeline L.p.
Operator Street Address
1300 Main Street
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2020-11-23 12:40:00
Location Latitude
32.00734
Location Longitude
-102.04163
Commodity Released Type
Crude Oil
Unintentional Release Bbls
1
Recovered Bbls
1
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
Incident Identified Datetime
2020-11-23 12:40:00
System Part Involved
Onshore Terminal/tank Farm Equipment And Piping
On Off Shore
Onshore
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2020-11-23 13:30:00
Restart Datetime
2021-02-04 13:30:00
On Site Datetime
2020-11-23 12:40:00
Nrc Rpt Num
Nrc Notification Not Required
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
0
Pipe Fac Name
Midland Station
Segment Name
8'' Row 3 Fill Line
Onshore State Abbreviation
Tx
Onshore Postal Code
79706
Onshore City Name
Not Within A Municipality
Onshore County Name
Midland
Designated Location
Milepost/valve Station
Designated Name
Station Pipin
Federal
No
Location Type
Totally Contained On Operator-Controlled Property
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
36
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
8
Pipe Wall Thickness
0.322
Pipe Smys
35000
Pipe Specification
Api 5l
Pipe Seam Type
Erw � Unknown Frequency
Pipe Manufacturer
Unknown
Pipe Coating Type
Coal Tar
Installation Year
Unknown
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Other
Leak Type Other
Corrosion Pit-100% Metal Loss
Wildlife Impact Ind
No
Soil Contamination
Yes
Long Term Assessment
No
Remediation Ind
Yes
Soil Remed Ind
Yes
Water Contam Ind
No
Could Be Hca
No
Commodity Reached Hca
No
Est Cost Oper Paid
0
Est Cost Gas Released
43
Est Cost Prop Damage
37175
Est Cost Emergency
2000
Est Cost Environmental
200
Est Cost Other
0
Prpty
39418
Accident Psig
30
Mop Psig
285
Accident Pressure
Pressure Did Not Exceed Mop
Pressure Restriction 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
Yes
Cpm Detection Ind
No
Cpm Conf Ind
No
Investigation Status
Yes, specify investigation result(s): (select all that apply)
Invest No Schedule Ind
Yes
Invest No Schedule Ind Details
The Volume Released Was Below The Detection Limit At The Time Of Discovery, And The Leak Could Not Have Been Detected By The Control Center.
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 Other Basis Ind
Yes
Int Corrosion Basis Details
Lab Analysis Of Pit Deposit Composition And Bacterial Serial Dilution.
Int Low Point Pipe Loc Ind
Yes
Corrosion Inhibitors
Yes
Corrosion Lining
No
Cleaning Dewatering
Not Applicable - Not Mainline Pipe
Corrosion Coupons
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
J***** M********
Preparer Title
Project Engineer
Preparer Email
J***************@c**********.com
Preparer Telephone
346-803-2869
Prepared Date
2021-03-10 00:00:00
Authorizer Name
C**** C*********
Authorizer Telephone
346-803-2827
Authorizer Title
Director Integrity Management
Authorizer Email
C***************@c**********.com
Narrative
On november 23, 2020, at approximately 12:40 cst, a centurion pipeline l.P. (cpl) employee discovered a leak in cpl's midland station near midland, texas in midland county, texas. Cpl determined the source of the leak to be station piping and promptly isolated the leak. However, one (1) barrel of crude oil was released. The contaminated soil was remediated on site. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to the texas railroad commission, office of pipeline safety at 1320 cst on november 23, 2020, and was issued incident number 2297 in reference to the incident. At the time of this writing, the repair of the station piping is scheduled and the root cause failure analysis will be conducted pending the removal of the damaged piping segment. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and costs associated with repairing the station piping will be submitted via supplemental report(s). Supplemental filed on 03/10/2021: updates include part a-14b; part c-6; part d-8c, 8d, 8e and 8g; part e-5f and 7; and part g. During the root cause failure analysis, cpl determined under-deposit corrosion caused the failure, which resulted from multiple contributing factors. Previously stagnant conditions caused water and solids to deposit near a girth weld on the bottom of a low point in the station piping, and a corrosion cell formed. The corrosion rate increased due to a galvanic couple between the iron sulfide deposit and the steel pipe, which was further exacerbated by a galvanic couple between two different ages of pipe. The combination of the iron sulfide deposit and a paraffin deposit prevented the corrosion mitigation chemicals from reaching the steel surface and reduced their effectiveness. Cpl replaced the entire segment containing the low point and removed the two different ages of pipe. Additionally, cpl will flush and treat the new segment of piping with corrosion mitigation chemicals if a period of no flow exists longer than 90 days. Cpl believes eliminating the contributing factors will prevent similar accidents from occurring.
| Report Received Date | 2020-12-21 00:00:00 |
|---|---|
| Iyear | 2020 |
| Report Number | 20200337 |
| Supplemental Number | 34975 |
| Report Type | Supplemental Final |
| Operator Id | 31888 PHMSA Enforcement |
| Name | Centurion Pipeline L.p. |
| Operator Street Address | 1300 Main Street |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2020-11-23 12:40:00 |
| Location Latitude | 32.00734 Google Maps OpenStreetMap |
| Location Longitude | -102.04163 Google Maps OpenStreetMap |
| Commodity Released Type | Crude Oil |
| Unintentional Release Bbls | 1 |
| Recovered Bbls | 1 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| Incident Identified Datetime | 2020-11-23 12:40:00 |
| System Part Involved | Onshore Terminal/tank Farm Equipment And Piping |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2020-11-23 13:30:00 |
| Restart Datetime | 2021-02-04 13:30:00 |
| On Site Datetime | 2020-11-23 12:40:00 |
| Nrc Rpt Num | Nrc Notification Not Required NRC Report How to search |
| Ignite Ind | No |
| Explode Ind | No |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Midland Station |
| Segment Name | 8'' Row 3 Fill Line |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 79706 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Midland |
| Designated Location | Milepost/valve Station |
| Designated Name | Station Pipin |
| Federal | No |
| Location Type | Totally Contained On Operator-Controlled Property |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 36 |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 8 |
| Pipe Wall Thickness | 0.322 |
| Pipe Smys | 35000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Erw � Unknown Frequency |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Coal Tar |
| Installation Year | Unknown |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Other |
| Leak Type Other | Corrosion Pit-100% Metal Loss |
| Wildlife Impact Ind | No |
| Soil Contamination | Yes |
| Long Term Assessment | No |
| Remediation Ind | Yes |
| Soil Remed Ind | Yes |
| Water Contam Ind | No |
| Could Be Hca | No |
| Commodity Reached Hca | No |
| Est Cost Oper Paid | 0 |
| Est Cost Gas Released | 43 |
| Est Cost Prop Damage | 37175 |
| Est Cost Emergency | 2000 |
| Est Cost Environmental | 200 |
| Est Cost Other | 0 |
| Prpty | 39418 |
| Accident Psig | 30 |
| Mop Psig | 285 |
| Accident Pressure | Pressure Did Not Exceed Mop |
| Pressure Restriction 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 | Yes |
| Cpm Detection Ind | No |
| Cpm Conf Ind | No |
| Investigation Status | Yes, specify investigation result(s): (select all that apply) |
| Invest No Schedule Ind | Yes |
| Invest No Schedule Ind Details | The Volume Released Was Below The Detection Limit At The Time Of Discovery, And The Leak Could Not Have Been Detected By The Control Center. |
| 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 Other Basis Ind | Yes |
| Int Corrosion Basis Details | Lab Analysis Of Pit Deposit Composition And Bacterial Serial Dilution. |
| Int Low Point Pipe Loc Ind | Yes |
| Corrosion Inhibitors | Yes |
| Corrosion Lining | No |
| Cleaning Dewatering | Not Applicable - Not Mainline Pipe |
| Corrosion Coupons | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | J***** M******** |
| Preparer Title | Project Engineer |
| Preparer Email | J***************@c**********.com |
| Preparer Telephone | 346-803-2869 |
| Prepared Date | 2021-03-10 00:00:00 |
| Authorizer Name | C**** C********* |
| Authorizer Telephone | 346-803-2827 |
| Authorizer Title | Director Integrity Management |
| Authorizer Email | C***************@c**********.com |
| Narrative | On november 23, 2020, at approximately 12:40 cst, a centurion pipeline l.P. (cpl) employee discovered a leak in cpl's midland station near midland, texas in midland county, texas. Cpl determined the source of the leak to be station piping and promptly isolated the leak. However, one (1) barrel of crude oil was released. The contaminated soil was remediated on site. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to the texas railroad commission, office of pipeline safety at 1320 cst on november 23, 2020, and was issued incident number 2297 in reference to the incident. At the time of this writing, the repair of the station piping is scheduled and the root cause failure analysis will be conducted pending the removal of the damaged piping segment. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and costs associated with repairing the station piping will be submitted via supplemental report(s). Supplemental filed on 03/10/2021: updates include part a-14b; part c-6; part d-8c, 8d, 8e and 8g; part e-5f and 7; and part g. During the root cause failure analysis, cpl determined under-deposit corrosion caused the failure, which resulted from multiple contributing factors. Previously stagnant conditions caused water and solids to deposit near a girth weld on the bottom of a low point in the station piping, and a corrosion cell formed. The corrosion rate increased due to a galvanic couple between the iron sulfide deposit and the steel pipe, which was further exacerbated by a galvanic couple between two different ages of pipe. The combination of the iron sulfide deposit and a paraffin deposit prevented the corrosion mitigation chemicals from reaching the steel surface and reduced their effectiveness. Cpl replaced the entire segment containing the low point and removed the two different ages of pipe. Additionally, cpl will flush and treat the new segment of piping with corrosion mitigation chemicals if a period of no flow exists longer than 90 days. Cpl believes eliminating the contributing factors will prevent similar accidents from occurring. |
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