Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2022-10-03 — OK
Operator
Monroe Gas Storage Company, Llc
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$428,974
Incident datetime
2022-10-03 16:46
Report number
Location
OK
Narrative
While performing routine rounds a monroe gas storage employee arrived at the t (t is referred to as where the well road from the east gate meets the well road that leads left towards well #7 and right toward wells #15,16,17, &9) approximate at 1646 and discovered the fire coming from what we now know was the 12' east lateral. After assessing the location of the incident, the employee begin calling in additional personnel and emergency officials to assist while shutting down the facility once additional personnel arrive the line was isolated manually and allowed to burn itself out. Monroe gas storage employees directed the fire department to the incident area and requested that they actively cooled the surrounding area to ensure the fire was contained. The fire was out, and incident contained approximately 40 minutes after discovery. The identified internal corrosion was consistent with mesa corrosion, typically occurring in a carbon dioxide (CO2) environment likely exacerbated via the presence of salt water and sand (resulting in an under-deposit phenomenon). To mitigate the damage from the failure and identified corrosion mgs performed the following: replaced in kind 42ft north of point of failure and 801 ft west of point of failure. Replaced in kind one 90-degree elbow. Mgs also installed a 2 inch low point drain. The determination of how much of pipe needed to be replace was made using a combination of visual inspection, hand-held ut gauge and guided wave technology. Guided wave technology was utilized upstream and downstream of replaced pipe, of which no additional integrity issues were found and no follow-ups were recommended. The 2 inch low point drain was the first phase of steps mgs is taking to prevent recurrence, the second includes developing and implementing a pigging and chemical treatment plan prior to bringing the 12' east lateral in service.
Detailed record list
Report Received Date
2022-11-10 00:00:00
Iyear
2022
Report Number
20220120
Supplemental Number
38555
Report Type
Supplemental Final
Operator Id
32374
Name
Monroe Gas Storage Company, Llc
Operator Street Address
One Williams Center
Operator City Name
Tulsa
Operator State Abbreviation
OK
Operator Postal Code
74172
Local Datetime
2022-10-03 16:47:00
Time Zone
Central
Daylight Savings Ind
No
Location Latitude
34.007757
Location Longitude
-88.451679
Nrc Rpt Num
1348951
Nrc Rpt Datetime
2022-10-03 17:38:00
Additional Nrc Report Numbers
1349098
Commodity Released Type
Natural Gas
Unintentional Release
1556.3
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Status When Identified
Normal Operation, Includes Pauses During Maintenance
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2022-10-03 17:30:00
Restart Datetime
2022-10-11 11:05:00
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Initial Responder Com Datetime
2022-10-03 16:55:00
Ignite Ind
Yes
Ignite Datetime
2022-10-03 16:46:00
How Extinguished
Allowed To Burn Out
Gas Consumed By Fire In Mcf
358.3
Explode Ind
No
Upstream Action Taken
Valve Closure
Upstream Valve Close Datetime
2022-10-03 16:57:00
Downstream Action Taken
Valve Closure
Downstream Vlv Close Datetime
2022-10-03 16:58:00
Num Pub Evacuated
0
Incident Identified Datetime
2022-10-03 16:46:00
On Site Datetime
2022-10-03 16:57:00
On Off Shore
Onshore
Onshore State Abbreviation
Ms
Onshore Postal Code
38821
Onshore City Name
Not Within A Municipality
Onshore County Name
Monroe
Designated Location
Milepost
Designated Name
8+47.1
Pipe Fac Name
Monroe Gas Storage
Segment Name
12" East Lateral
Federal
No
Location Type
Operator-Controlled Property
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
120
Other Underground Facilities
No
Crossing
No
Pipe Facility Type
Interstate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
12
Puddle Weld Ind
No
Pipe Wall Thickness
0.375
Pipe Smys
52000
Pipe Specification
Api 5l
Pipe Seam Type
Longitudinal Erw - High Frequency
Pipe Manufacturer
Edgar Carbon
Pipe Coating Type
Epoxy
Coating Applied Ind
Yes
Installation Year
2009
Manufactured Year
2009
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
300
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
45000
Est Cost Unintentional Release
10707
Est Cost Intentional Release
0
Est Cost Prop Damage
428974
Est Cost Emergency
0
Est Cost Other
0
Gas Cost In Mcf
6.88
Prpty
484681
Num Persons Hosp Not Ovnght
0
Num Injured Treated By Emt
0
Num Resident Building Affctd
0
Num Business Building Affctd
0
Wildlife Impact Ind
No
Accident Psig
931
Gas Flow In Pipe In Mcf
6
Mop Psig
1314
Mop Cfr Section
192.619(A)(2)
Maop Established Date
2009-04-06 00:00:00
Maop Reversal Flow Ind
No
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Gas Required Odorized Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
2682
Internal Inspection Ind
No
Other Inspection Ind
Yes
Internal Inspection Details
The Line Was Not Installed With A Launcher And Receiver.
Operation Complications Ind
No
Pipeline Function
Transmission In Storage Field
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
No
Scada Conf Ind
No
Accident Identifier
Ground Patrol By Operator Or Its Contractor
Operator Type
Operator Employee
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
Yes
Contractor Drug Test Ind
No
Num Employees Tested
1
Num Employees Failed
0
Cause
Corrosion Failure
Cause Details
Internal Corrosion
Internal External
Internal Corrosion
Int Visual Exam Results
Localized Pitting
Int Microbiological Ind
Yes
Int Field Exam Basis Ind
Yes
Int Low Point Pipe 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
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
R* S******
Preparer Title
Operations Compliance Manager
Preparer Email
R*********@h********.com
Preparer Telephone
3182548951
Local Contact Name
R* J S******
Local Contact Email
R*********@h********.com
Local Contact Telephone
13182241124
Authorizer Name
K****** F****
Authorizer Title
Vp Operations
Authorizer Telephone
3182548951
Authorizer Email
K************@h********.com
Narrative
While performing routine rounds a monroe gas storage employee arrived at the t (t is referred to as where the well road from the east gate meets the well road that leads left towards well #7 and right toward wells #15,16,17, &9) approximate at 1646 and discovered the fire coming from what we now know was the 12' east lateral. After assessing the location of the incident, the employee begin calling in additional personnel and emergency officials to assist while shutting down the facility once additional personnel arrive the line was isolated manually and allowed to burn itself out. Monroe gas storage employees directed the fire department to the incident area and requested that they actively cooled the surrounding area to ensure the fire was contained. The fire was out, and incident contained approximately 40 minutes after discovery. The identified internal corrosion was consistent with mesa corrosion, typically occurring in a carbon dioxide (CO2) environment likely exacerbated via the presence of salt water and sand (resulting in an under-deposit phenomenon). To mitigate the damage from the failure and identified corrosion mgs performed the following: replaced in kind 42ft north of point of failure and 801 ft west of point of failure. Replaced in kind one 90-degree elbow. Mgs also installed a 2 inch low point drain. The determination of how much of pipe needed to be replace was made using a combination of visual inspection, hand-held ut gauge and guided wave technology. Guided wave technology was utilized upstream and downstream of replaced pipe, of which no additional integrity issues were found and no follow-ups were recommended. The 2 inch low point drain was the first phase of steps mgs is taking to prevent recurrence, the second includes developing and implementing a pigging and chemical treatment plan prior to bringing the 12' east lateral in service.
| Report Received Date | 2022-11-10 00:00:00 |
|---|---|
| Iyear | 2022 |
| Report Number | 20220120 |
| Supplemental Number | 38555 |
| Report Type | Supplemental Final |
| Operator Id | 32374 PHMSA Enforcement |
| Name | Monroe Gas Storage Company, Llc |
| Operator Street Address | One Williams Center |
| Operator City Name | Tulsa |
| Operator State Abbreviation | OK |
| Operator Postal Code | 74172 |
| Local Datetime | 2022-10-03 16:47:00 |
| Time Zone | Central |
| Daylight Savings Ind | No |
| Location Latitude | 34.007757 Google Maps OpenStreetMap |
| Location Longitude | -88.451679 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1348951 NRC Report How to search |
| Nrc Rpt Datetime | 2022-10-03 17:38:00 |
| Additional Nrc Report Numbers | 1349098 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 1556.3 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Status When Identified | Normal Operation, Includes Pauses During Maintenance |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2022-10-03 17:30:00 |
| Restart Datetime | 2022-10-11 11:05:00 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Initial Responder Com Datetime | 2022-10-03 16:55:00 |
| Ignite Ind | Yes |
| Ignite Datetime | 2022-10-03 16:46:00 |
| How Extinguished | Allowed To Burn Out |
| Gas Consumed By Fire In Mcf | 358.3 |
| Explode Ind | No |
| Upstream Action Taken | Valve Closure |
| Upstream Valve Close Datetime | 2022-10-03 16:57:00 |
| Downstream Action Taken | Valve Closure |
| Downstream Vlv Close Datetime | 2022-10-03 16:58:00 |
| Num Pub Evacuated | 0 |
| Incident Identified Datetime | 2022-10-03 16:46:00 |
| On Site Datetime | 2022-10-03 16:57:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Ms |
| Onshore Postal Code | 38821 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Monroe |
| Designated Location | Milepost |
| Designated Name | 8+47.1 |
| Pipe Fac Name | Monroe Gas Storage |
| Segment Name | 12" East Lateral |
| Federal | No |
| Location Type | Operator-Controlled Property |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 120 |
| Other Underground Facilities | No |
| Crossing | No |
| Pipe Facility Type | Interstate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 12 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.375 |
| Pipe Smys | 52000 |
| Pipe Specification | Api 5l |
| Pipe Seam Type | Longitudinal Erw - High Frequency |
| Pipe Manufacturer | Edgar Carbon |
| Pipe Coating Type | Epoxy |
| Coating Applied Ind | Yes |
| Installation Year | 2009 |
| Manufactured Year | 2009 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 300 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 45000 |
| Est Cost Unintentional Release | 10707 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 428974 |
| Est Cost Emergency | 0 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 6.88 |
| Prpty | 484681 |
| Num Persons Hosp Not Ovnght | 0 |
| Num Injured Treated By Emt | 0 |
| Num Resident Building Affctd | 0 |
| Num Business Building Affctd | 0 |
| Wildlife Impact Ind | No |
| Accident Psig | 931 |
| Gas Flow In Pipe In Mcf | 6 |
| Mop Psig | 1314 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Maop Established Date | 2009-04-06 00:00:00 |
| Maop Reversal Flow Ind | No |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Gas Required Odorized Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 2682 |
| Internal Inspection Ind | No |
| Other Inspection Ind | Yes |
| Internal Inspection Details | The Line Was Not Installed With A Launcher And Receiver. |
| Operation Complications Ind | No |
| Pipeline Function | Transmission In Storage Field |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | No |
| Scada Conf Ind | No |
| Accident Identifier | Ground Patrol By Operator Or Its Contractor |
| Operator Type | Operator Employee |
| 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 | Yes |
| Contractor Drug Test Ind | No |
| Num Employees Tested | 1 |
| Num Employees Failed | 0 |
| Cause | Corrosion Failure |
| Cause Details | Internal Corrosion |
| Internal External | Internal Corrosion |
| Int Visual Exam Results | Localized Pitting |
| Int Microbiological Ind | Yes |
| Int Field Exam Basis Ind | Yes |
| Int Low Point Pipe 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 | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | R* S****** |
| Preparer Title | Operations Compliance Manager |
| Preparer Email | R*********@h********.com |
| Preparer Telephone | 3182548951 |
| Local Contact Name | R* J S****** |
| Local Contact Email | R*********@h********.com |
| Local Contact Telephone | 13182241124 |
| Authorizer Name | K****** F**** |
| Authorizer Title | Vp Operations |
| Authorizer Telephone | 3182548951 |
| Authorizer Email | K************@h********.com |
| Narrative | While performing routine rounds a monroe gas storage employee arrived at the t (t is referred to as where the well road from the east gate meets the well road that leads left towards well #7 and right toward wells #15,16,17, &9) approximate at 1646 and discovered the fire coming from what we now know was the 12' east lateral. After assessing the location of the incident, the employee begin calling in additional personnel and emergency officials to assist while shutting down the facility once additional personnel arrive the line was isolated manually and allowed to burn itself out. Monroe gas storage employees directed the fire department to the incident area and requested that they actively cooled the surrounding area to ensure the fire was contained. The fire was out, and incident contained approximately 40 minutes after discovery. The identified internal corrosion was consistent with mesa corrosion, typically occurring in a carbon dioxide (CO2) environment likely exacerbated via the presence of salt water and sand (resulting in an under-deposit phenomenon). To mitigate the damage from the failure and identified corrosion mgs performed the following: replaced in kind 42ft north of point of failure and 801 ft west of point of failure. Replaced in kind one 90-degree elbow. Mgs also installed a 2 inch low point drain. The determination of how much of pipe needed to be replace was made using a combination of visual inspection, hand-held ut gauge and guided wave technology. Guided wave technology was utilized upstream and downstream of replaced pipe, of which no additional integrity issues were found and no follow-ups were recommended. The 2 inch low point drain was the first phase of steps mgs is taking to prevent recurrence, the second includes developing and implementing a pigging and chemical treatment plan prior to bringing the 12' east lateral in service. |
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