Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2021-11-06 — TX
Operator
Centurion Pipeline L.p.
Cause
Corrosion Failure
Commodity
Crude Oil
Program
HL
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$7,500
Incident datetime
2021-11-06 11:15
Report number
Location
TX
Narrative
On november 6, 2021, at 11:15am 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 the mtf terminal pump p-a1, arco meter #2 strainer and promptly isolated the leak. Five (5) barrels of crude oil was released and recovered. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to texas railroad commission, office of pipeline safety at 12:06pm cst on november 6, 2021. At the time of this writing, the repair has been scheduled and the root cause failure analysis will be conducted pending the sample examinations. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and updates to cost, if applicable, will be submitted via supplemental report(s). Supplemental final report filed on december 14, 2021: cpl's detailed investigation determined that under-deposit microbiologically influenced corrosion (mic) caused the failure. The contributing factors include water drop-out, solid deposits, and paraffin accumulation on the internal surface of the strainer drain pipe, which resulted in internal corrosion pits that weakened the threaded section of the drain pipe until the threads broke during normal operation. A previous period of stagnant conditions in the station piping allowed water, solids, and paraffin to deposit in the strainer drain pipe, and a bacteria colony formed a microbiologically influenced corrosion pit. The corrosion rate within the pits increased due to a galvanic couple between the iron sulfide and iron magnetite compounds, verified by lab analysis, and the steel pipe. The paraffin accumulation prevented the incoming oil that was treated with corrosion mitigation and biocide chemicals from reaching the bacteria colony and the iron sulfide and deposits, thereby preventing the normal action of the chemicals. It must be concluded that this corrosion on the strainer drain pipe was not related to the chemical treatment of the crude oil or to any unexpected corrosiveness of the crude oil. Records show that the crude oil was uniformly treated with corrosion control chemicals and biocides, but the incident inspection and lab analysis proved that the corrosion control chemicals were prevented from reaching the biofilm by a layer of waxy paraffin. The following will occur as part of the p&m measure: 1. An evaluation of midland station pipeline and the subsets a through c. A) identify all piping at midland station that may have been affected by previous periods of stagnant or low flow conditions. B) determine which lines will be required for current and foreseeable operational and commercial commitments. C) prioritize piping based operational and commercial commitments. 2. Mitigate potential internal corrosion damage and remove underutilized piping from service following completion of step 1. A) remove low flow piping from service that will not be required for routine operations, which could be a temporary or permanent removal. B) replace low flow piping that will be required for routine operations. (pipeline replacements will be planned for future execution depending on scope of work.) c) develop an enhanced flushing program that would include paraffin solvents and biocides for piping remaining in the flushing program.
Detailed record list
Report Received Date
2021-12-01 00:00:00
Iyear
2021
Report Number
20210336
Supplemental Number
36131
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
2021-11-06 11:15:00
Location Latitude
32.005472
Location Longitude
-102.04086
Commodity Released Type
Crude Oil
Unintentional Release Bbls
5
Recovered Bbls
5
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
Incident Identified Datetime
2021-11-06 11:15:00
System Part Involved
Onshore Pump/meter Station Equipment And Piping
On Off Shore
Onshore
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2021-11-06 11:20:00
Restart Datetime
2021-11-08 18:21:00
On Site Datetime
2021-11-06 11:15:00
Nrc Rpt Num
Nrc Notification Not Required
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
0
Pipe Fac Name
Midland Station
Segment Name
Mtf Terminal Pump P-A1, Arco Meter #2 Strainer
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
Midland Sta.
Federal
No
Location Type
Totally Contained On Operator-Controlled Property
Incident Area Type
Aboveground
Incident Area Subtype
Typical Aboveground Facility Piping Or Appurtenance
Crossing
No
Pipe Facility Type
Intrastate
Item Involved
Pump
Installation 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
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
400
Est Cost Prop Damage
7500
Est Cost Emergency
1000
Est Cost Environmental
150
Est Cost Other
0
Prpty
9050
Accident Psig
46
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 Schedule Ind
Yes
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 Microbiological Ind
Yes
Int Field Exam Basis Ind
Yes
Int Metallurgical Basis Ind
Yes
Int Other Loc Ind
Yes
Corrosion Location Details
Corrosion Located On Drain Thread-O-Let Of 10'' Strainer (Manufacturer- Linc. Model: 150-Rf.)
Corrosion Inhibitors
Yes
Corrosion Lining
No
Cleaning Dewatering
Not Applicable - Not Mainline Pipe
Corrosion Coupons
Not Applicable - Not Mainline Pipe
Preparer Name
Y**** T*
Preparer Title
Pipeline Compliance Program Advisor
Preparer Email
Y******@c**********.com
Preparer Telephone
346-803-2718
Prepared Date
2021-12-14 00:00:00
Authorizer Name
T***** D*****
Authorizer Telephone
346-803-2830
Authorizer Title
Compliance Manager
Authorizer Email
T************@c**********.com
Narrative
On november 6, 2021, at 11:15am 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 the mtf terminal pump p-a1, arco meter #2 strainer and promptly isolated the leak. Five (5) barrels of crude oil was released and recovered. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to texas railroad commission, office of pipeline safety at 12:06pm cst on november 6, 2021. At the time of this writing, the repair has been scheduled and the root cause failure analysis will be conducted pending the sample examinations. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and updates to cost, if applicable, will be submitted via supplemental report(s). Supplemental final report filed on december 14, 2021: cpl's detailed investigation determined that under-deposit microbiologically influenced corrosion (mic) caused the failure. The contributing factors include water drop-out, solid deposits, and paraffin accumulation on the internal surface of the strainer drain pipe, which resulted in internal corrosion pits that weakened the threaded section of the drain pipe until the threads broke during normal operation. A previous period of stagnant conditions in the station piping allowed water, solids, and paraffin to deposit in the strainer drain pipe, and a bacteria colony formed a microbiologically influenced corrosion pit. The corrosion rate within the pits increased due to a galvanic couple between the iron sulfide and iron magnetite compounds, verified by lab analysis, and the steel pipe. The paraffin accumulation prevented the incoming oil that was treated with corrosion mitigation and biocide chemicals from reaching the bacteria colony and the iron sulfide and deposits, thereby preventing the normal action of the chemicals. It must be concluded that this corrosion on the strainer drain pipe was not related to the chemical treatment of the crude oil or to any unexpected corrosiveness of the crude oil. Records show that the crude oil was uniformly treated with corrosion control chemicals and biocides, but the incident inspection and lab analysis proved that the corrosion control chemicals were prevented from reaching the biofilm by a layer of waxy paraffin. The following will occur as part of the p&m measure: 1. An evaluation of midland station pipeline and the subsets a through c. A) identify all piping at midland station that may have been affected by previous periods of stagnant or low flow conditions. B) determine which lines will be required for current and foreseeable operational and commercial commitments. C) prioritize piping based operational and commercial commitments. 2. Mitigate potential internal corrosion damage and remove underutilized piping from service following completion of step 1. A) remove low flow piping from service that will not be required for routine operations, which could be a temporary or permanent removal. B) replace low flow piping that will be required for routine operations. (pipeline replacements will be planned for future execution depending on scope of work.) c) develop an enhanced flushing program that would include paraffin solvents and biocides for piping remaining in the flushing program.
| Report Received Date | 2021-12-01 00:00:00 |
|---|---|
| Iyear | 2021 |
| Report Number | 20210336 |
| Supplemental Number | 36131 |
| 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 | 2021-11-06 11:15:00 |
| Location Latitude | 32.005472 Google Maps OpenStreetMap |
| Location Longitude | -102.04086 Google Maps OpenStreetMap |
| Commodity Released Type | Crude Oil |
| Unintentional Release Bbls | 5 |
| Recovered Bbls | 5 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| Incident Identified Datetime | 2021-11-06 11:15:00 |
| System Part Involved | Onshore Pump/meter Station Equipment And Piping |
| On Off Shore | Onshore |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2021-11-06 11:20:00 |
| Restart Datetime | 2021-11-08 18:21:00 |
| On Site Datetime | 2021-11-06 11:15:00 |
| 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 | Mtf Terminal Pump P-A1, Arco Meter #2 Strainer |
| 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 | Midland Sta. |
| Federal | No |
| Location Type | Totally Contained On Operator-Controlled Property |
| Incident Area Type | Aboveground |
| Incident Area Subtype | Typical Aboveground Facility Piping Or Appurtenance |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| Item Involved | Pump |
| Installation 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 |
| 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 | 400 |
| Est Cost Prop Damage | 7500 |
| Est Cost Emergency | 1000 |
| Est Cost Environmental | 150 |
| Est Cost Other | 0 |
| Prpty | 9050 |
| Accident Psig | 46 |
| 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 Schedule Ind | Yes |
| 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 Microbiological Ind | Yes |
| Int Field Exam Basis Ind | Yes |
| Int Metallurgical Basis Ind | Yes |
| Int Other Loc Ind | Yes |
| Corrosion Location Details | Corrosion Located On Drain Thread-O-Let Of 10'' Strainer (Manufacturer- Linc. Model: 150-Rf.) |
| Corrosion Inhibitors | Yes |
| Corrosion Lining | No |
| Cleaning Dewatering | Not Applicable - Not Mainline Pipe |
| Corrosion Coupons | Not Applicable - Not Mainline Pipe |
| Preparer Name | Y**** T* |
| Preparer Title | Pipeline Compliance Program Advisor |
| Preparer Email | Y******@c**********.com |
| Preparer Telephone | 346-803-2718 |
| Prepared Date | 2021-12-14 00:00:00 |
| Authorizer Name | T***** D***** |
| Authorizer Telephone | 346-803-2830 |
| Authorizer Title | Compliance Manager |
| Authorizer Email | T************@c**********.com |
| Narrative | On november 6, 2021, at 11:15am 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 the mtf terminal pump p-a1, arco meter #2 strainer and promptly isolated the leak. Five (5) barrels of crude oil was released and recovered. No injuries, fatalities, or fires were associated with this incident. Cpl reported the leak to texas railroad commission, office of pipeline safety at 12:06pm cst on november 6, 2021. At the time of this writing, the repair has been scheduled and the root cause failure analysis will be conducted pending the sample examinations. The resulting information related to the cause of the leak, preventative and mitigative measures (p&m), and updates to cost, if applicable, will be submitted via supplemental report(s). Supplemental final report filed on december 14, 2021: cpl's detailed investigation determined that under-deposit microbiologically influenced corrosion (mic) caused the failure. The contributing factors include water drop-out, solid deposits, and paraffin accumulation on the internal surface of the strainer drain pipe, which resulted in internal corrosion pits that weakened the threaded section of the drain pipe until the threads broke during normal operation. A previous period of stagnant conditions in the station piping allowed water, solids, and paraffin to deposit in the strainer drain pipe, and a bacteria colony formed a microbiologically influenced corrosion pit. The corrosion rate within the pits increased due to a galvanic couple between the iron sulfide and iron magnetite compounds, verified by lab analysis, and the steel pipe. The paraffin accumulation prevented the incoming oil that was treated with corrosion mitigation and biocide chemicals from reaching the bacteria colony and the iron sulfide and deposits, thereby preventing the normal action of the chemicals. It must be concluded that this corrosion on the strainer drain pipe was not related to the chemical treatment of the crude oil or to any unexpected corrosiveness of the crude oil. Records show that the crude oil was uniformly treated with corrosion control chemicals and biocides, but the incident inspection and lab analysis proved that the corrosion control chemicals were prevented from reaching the biofilm by a layer of waxy paraffin. The following will occur as part of the p&m measure: 1. An evaluation of midland station pipeline and the subsets a through c. A) identify all piping at midland station that may have been affected by previous periods of stagnant or low flow conditions. B) determine which lines will be required for current and foreseeable operational and commercial commitments. C) prioritize piping based operational and commercial commitments. 2. Mitigate potential internal corrosion damage and remove underutilized piping from service following completion of step 1. A) remove low flow piping from service that will not be required for routine operations, which could be a temporary or permanent removal. B) replace low flow piping that will be required for routine operations. (pipeline replacements will be planned for future execution depending on scope of work.) c) develop an enhanced flushing program that would include paraffin solvents and biocides for piping remaining in the flushing program. |
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