Incident details
Operator, cause, commodity and consequences with raw source fields.
HL incident on 2023-08-04 — KS
Operator
Chs Mcpherson Refinery Inc.
Cause
Corrosion Failure
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)
$20,000
Incident datetime
2023-08-04 00:00 UTC
Report number
Location
KS
Narrative
Operators responding to lel alarms in well #9 vicinity observed liquid product at the ground surface above known ngl piping. Operators isolated the piping segment by closing nearby valves, which stopped the release. Vacuum trucks were utilized to de-inventory all affected piping. The soil near the release location was excavated and affected piping was exposed to determine the leak location. A pin hole was identified by visual inspection. The pinhole is located in a segment of piping that is not at a low point. The affected deadleg was eliminated by cutting out the tee at the branch connection and the failed pipe was sent for third party metallurgical analysis. The analysis determined that aqueous corrosion was the likely cause of failure. Chsmri plans to take the following steps to identify further corrosion impacts to the effected piping circuits: 1. Perform inspection of dead leg piping and develop plan to remove piping. 2. Evaluate products for active corrosion contributions. 3. Perform additional inspections on non-dead leg piping. 4. Where possible, flush dead legs on a quarterly basis. 5. Perform hydrotest after dead leg removal.
Detailed record list
Report Received Date
2023-08-04 00:00:00
Iyear
2023
Report Number
20230177
Supplemental Number
39020
Report Type
Supplemental Final
Operator Id
26065
Name
Chs Mcpherson Refinery Inc.
Operator Street Address
2000 S. Main
Operator City Name
Mcpherson
Operator State Abbreviation
KS
Operator Postal Code
67460
Time Zone
Central
Daylight Savings Ind
Yes
Location Latitude
38.37043
Location Longitude
-97.7825
Commodity Released Type
Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions
Commodity Subtype
Other
Commodity Details
Natural Gasoline
Unintentional Release Bbls
2.38
Recovered Bbls
2.38
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Accident Identifier
Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Or Pack Calculations)
System Part Involved
Onshore Equipment And Piping Associated With Belowground Storage
On Off Shore
Onshore
Status When Identified
Normal Operation, Includes Pauses Between Batches And During Maintenance
Shutdown Due Accident Ind
Yes
Still Shutdown Ind
Yes
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Nrc Rpt Num
1372782
Additional Nrc Report Numbers
1372960
Ignite Ind
No
Notify Qualified Indiv Ind
Yes
Oil Spill Removal Org Ind
No
Num Pub Evacuated
0
Pipe Fac Name
Chs Mri Conway Storage Terminal
Segment Name
#4 Ngl Facility Piping
Onshore State Abbreviation
Ks
Onshore Postal Code
67460
Onshore City Name
Not Within A Municipality
Onshore County Name
Mcpherson
Designated Location
Milepost
Designated Name
Conway Term
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
Puddle Weld Ind
No
Pipe Diameter
4
Pipe Wall Thickness
0.235
Pipe Smys
60000
Pipe Specification
A53b
Pipe Seam Type
Seamless
Pipe Manufacturer
Unknown
Pipe Coating Type
Fusion Bonded Epoxy(Fbe)
Coating Applied Ind
Unknown
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
Soil Remed Ind
Yes
Water Contam Ind
No
Could Be Hca
Yes
Commodity Reached Hca
No
Est Cost Oper Paid
0
Est Cost Gas Released
400
Est Cost Prop Damage
20000
Est Cost Emergency
5000
Est Cost Environmental
90000
Est Cost Other
500
Est Cost Other Details
Costs To Compile And Submit Phmsa Report.
Prpty
115900
Num Persons Hosp Not Ovnght
0
Num Injured Treated By Emt
0
Num Resident Building Affctd
0
Num Business Building Affctd
0
Accident Psig
168
Mop Psig
720
Mop Cfr Section
Component Design Pressure �195.406(A)(2)
Maop Established Date
2011-10-06 00:00:00
Maop Reversal Flow Ind
No
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
Yes
Scada Conf Ind
Yes
Cpm In Place Ind
No
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
Controller responded according to procedure and implemented corrective actions per plans. Failure due to piping corrosion and not related to controller activity.
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 Metallurgical Basis Ind
Yes
Int Dead Leg Loc Ind
Yes
Corrosion Inhibitors
No
Corrosion Lining
No
Cleaning Dewatering
Not Applicable - Not Mainline Pipe
Corrosion Coupons
Not Applicable - Not Mainline Pipe
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2019
Hydrtst Most Rcnt Pressure
1025
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Intrnl Cor Wtr Drpout Acid Ind
Yes
Preparer Name
M******* S*****
Preparer Title
Principal Dot Compliance
Preparer Email
M**************@c*****.com
Preparer Telephone
4066285293
Preparer Fax
4066285293
Prepared Date
2023-12-27 00:00:00
Local Contact Name
B**** P*****
Local Contact Email
B***********@c*****.com
Local Contact Telephone
620-241-9251
Authorizer Name
G*** B****
Authorizer Telephone
4066285200
Authorizer Title
Vp Pipelines And Terminals
Authorizer Email
G*********@c*****.comc
Narrative
Operators responding to lel alarms in well #9 vicinity observed liquid product at the ground surface above known ngl piping. Operators isolated the piping segment by closing nearby valves, which stopped the release. Vacuum trucks were utilized to de-inventory all affected piping. The soil near the release location was excavated and affected piping was exposed to determine the leak location. A pin hole was identified by visual inspection. The pinhole is located in a segment of piping that is not at a low point. The affected deadleg was eliminated by cutting out the tee at the branch connection and the failed pipe was sent for third party metallurgical analysis. The analysis determined that aqueous corrosion was the likely cause of failure. Chsmri plans to take the following steps to identify further corrosion impacts to the effected piping circuits: 1. Perform inspection of dead leg piping and develop plan to remove piping. 2. Evaluate products for active corrosion contributions. 3. Perform additional inspections on non-dead leg piping. 4. Where possible, flush dead legs on a quarterly basis. 5. Perform hydrotest after dead leg removal.
| Report Received Date | 2023-08-04 00:00:00 |
|---|---|
| Iyear | 2023 |
| Report Number | 20230177 |
| Supplemental Number | 39020 |
| Report Type | Supplemental Final |
| Operator Id | 26065 PHMSA Enforcement |
| Name | Chs Mcpherson Refinery Inc. |
| Operator Street Address | 2000 S. Main |
| Operator City Name | Mcpherson |
| Operator State Abbreviation | KS |
| Operator Postal Code | 67460 |
| Time Zone | Central |
| Daylight Savings Ind | Yes |
| Location Latitude | 38.37043 Google Maps OpenStreetMap |
| Location Longitude | -97.7825 Google Maps OpenStreetMap |
| Commodity Released Type | Refined And/or Petroleum Product (Non-Hvl) Which Is A Liquid At Ambient Conditions |
| Commodity Subtype | Other |
| Commodity Details | Natural Gasoline |
| Unintentional Release Bbls | 2.38 |
| Recovered Bbls | 2.38 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Accident Identifier | Scada-Based Information (Such As Alarm(S), Alert(S), Event(S), And/or Volume Or Pack Calculations) |
| System Part Involved | Onshore Equipment And Piping Associated With Belowground Storage |
| On Off Shore | Onshore |
| Status When Identified | Normal Operation, Includes Pauses Between Batches And During Maintenance |
| Shutdown Due Accident Ind | Yes |
| Still Shutdown Ind | Yes |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Nrc Rpt Num | 1372782 NRC Report How to search |
| Additional Nrc Report Numbers | 1372960 |
| Ignite Ind | No |
| Notify Qualified Indiv Ind | Yes |
| Oil Spill Removal Org Ind | No |
| Num Pub Evacuated | 0 |
| Pipe Fac Name | Chs Mri Conway Storage Terminal |
| Segment Name | #4 Ngl Facility Piping |
| Onshore State Abbreviation | Ks |
| Onshore Postal Code | 67460 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Mcpherson |
| Designated Location | Milepost |
| Designated Name | Conway Term |
| 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 |
| Puddle Weld Ind | No |
| Pipe Diameter | 4 |
| Pipe Wall Thickness | 0.235 |
| Pipe Smys | 60000 |
| Pipe Specification | A53b |
| Pipe Seam Type | Seamless |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Fusion Bonded Epoxy(Fbe) |
| Coating Applied Ind | Unknown |
| 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 |
| Soil Remed Ind | Yes |
| Water Contam Ind | No |
| Could Be Hca | Yes |
| Commodity Reached Hca | No |
| Est Cost Oper Paid | 0 |
| Est Cost Gas Released | 400 |
| Est Cost Prop Damage | 20000 |
| Est Cost Emergency | 5000 |
| Est Cost Environmental | 90000 |
| Est Cost Other | 500 |
| Est Cost Other Details | Costs To Compile And Submit Phmsa Report. |
| Prpty | 115900 |
| Num Persons Hosp Not Ovnght | 0 |
| Num Injured Treated By Emt | 0 |
| Num Resident Building Affctd | 0 |
| Num Business Building Affctd | 0 |
| Accident Psig | 168 |
| Mop Psig | 720 |
| Mop Cfr Section | Component Design Pressure �195.406(A)(2) View CFR 49 §192 |
| Maop Established Date | 2011-10-06 00:00:00 |
| Maop Reversal Flow Ind | No |
| 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 | Yes |
| Scada Conf Ind | Yes |
| Cpm In Place Ind | No |
| 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 | Controller responded according to procedure and implemented corrective actions per plans. Failure due to piping corrosion and not related to controller activity. |
| 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 Metallurgical Basis Ind | Yes |
| Int Dead Leg Loc Ind | Yes |
| Corrosion Inhibitors | No |
| Corrosion Lining | No |
| Cleaning Dewatering | Not Applicable - Not Mainline Pipe |
| Corrosion Coupons | Not Applicable - Not Mainline Pipe |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2019 |
| Hydrtst Most Rcnt Pressure | 1025 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Intrnl Cor Wtr Drpout Acid Ind | Yes |
| Preparer Name | M******* S***** |
| Preparer Title | Principal Dot Compliance |
| Preparer Email | M**************@c*****.com |
| Preparer Telephone | 4066285293 |
| Preparer Fax | 4066285293 |
| Prepared Date | 2023-12-27 00:00:00 |
| Local Contact Name | B**** P***** |
| Local Contact Email | B***********@c*****.com |
| Local Contact Telephone | 620-241-9251 |
| Authorizer Name | G*** B**** |
| Authorizer Telephone | 4066285200 |
| Authorizer Title | Vp Pipelines And Terminals |
| Authorizer Email | G*********@c*****.comc |
| Narrative | Operators responding to lel alarms in well #9 vicinity observed liquid product at the ground surface above known ngl piping. Operators isolated the piping segment by closing nearby valves, which stopped the release. Vacuum trucks were utilized to de-inventory all affected piping. The soil near the release location was excavated and affected piping was exposed to determine the leak location. A pin hole was identified by visual inspection. The pinhole is located in a segment of piping that is not at a low point. The affected deadleg was eliminated by cutting out the tee at the branch connection and the failed pipe was sent for third party metallurgical analysis. The analysis determined that aqueous corrosion was the likely cause of failure. Chsmri plans to take the following steps to identify further corrosion impacts to the effected piping circuits: 1. Perform inspection of dead leg piping and develop plan to remove piping. 2. Evaluate products for active corrosion contributions. 3. Perform additional inspections on non-dead leg piping. 4. Where possible, flush dead legs on a quarterly basis. 5. Perform hydrotest after dead leg removal. |
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