Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2024-10-17 — 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)
$400,000
Incident datetime
2024-10-17 00:00 UTC
Report number
Location
OK
Narrative
On friday afternoon 9/20/24 at 13:21 ct, a technician at the monroe gas storage compressor station observed small bubbles rising within a puddle of water while doing regular inspection rounds within the fenced facility. After confirming the presence of natural gas at the location and suspecting a pinhole leak, the 18" eastside gas transmission line was isolated by manually closing the downstream valves. Because the line was not flowing at the time, the upstream valves were already closed. The effected line segment was isolated by 14:13 ct. After initial coordination regarding possible cost of repair, it was determined to classify the event as an incident and notify the national response center (nrc). The nrc was notified by the williams security operations center at 15:27 ct. The pipeline was safely blown down with lock out / tag out completed by 19:20 ct that evening. Due to the pipeline's 10' depth in the area, it took multiple days for contractors to clean the line through cleaning pigs, purge with nitrogen and pothole through hydrovacing to pinpoint the leak location. Once identified (through detecting the presence of nitrogen), the leak location was fully and safely excavated (considering the significant depth) on 10/14/24. As of 10/15/24, internal corrosion was found at the pinhole leak location. The effected pipe immediately near the leak location was cut-out on 10/17/24 and sent to a lab for analysis. Williams operations, pipeline integrity and construction teams established a conservative plan to replace necessary pipe and return the line to service. Approximately 350 feet of 18-inch pipe in the low area of the pipeline (within the facility) was replaced and hydrotested. The line was returned to service on 11/9/2024. The cause is suspected to be sulfate reducing bacteria microbiologically influenced corrosion (srb-mic) based on lab results. Representatives from operations, management and pipeline integrity have established an internal corrosion mitigation plan to prevent reoccurrence. Coupons have been installed at each well head location and other locations, based on internal corrosion data gathered, operations, management, compliance and corrosion department will deem if more locations are needed. A pigging program that includes all 13 laterals is forthcoming, with additional focus on the 18" lateral.
Detailed record list
Report Received Date
2024-10-17 00:00:00
Iyear
2024
Report Number
20240118
Supplemental Number
40404
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
Time Zone
Central
Daylight Savings Ind
Yes
Location Latitude
34.01305
Location Longitude
-88.45674
Nrc Rpt Num
1411453
Additional Nrc Report Numbers
1411606
Commodity Released Type
Natural Gas
Unintentional Release
164
Intentional Release
530
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
Still Shutdown Ind
Yes
Communication State Fed Ind
No
Ignite Ind
No
Upstream Action Taken
Valve Closure
Downstream Action Taken
Valve Closure
Num Pub Evacuated
0
On Off Shore
Onshore
Onshore State Abbreviation
Ms
Onshore Postal Code
38821
Onshore City Name
Amory
Onshore County Name
Monroe
Designated Location
Milepost
Designated Name
0.01
Pipe Fac Name
Monroe Gas Storage Facility
Segment Name
18" Eastside Transmission Line
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
18
Puddle Weld Ind
No
Pipe Wall Thickness
0.375
Pipe Smys
60000
Pipe Specification
Api 5l Psl2
Pipe Seam Type
Longitudinal Erw - High Frequency
Pipe Manufacturer
Unknown
Pipe Coating Type
Epoxy
Coating Applied Ind
Yes
Installation Year
2009
Manufactured Year
2008
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
471
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
492
Est Cost Intentional Release
1590
Est Cost Prop Damage
400000
Est Cost Emergency
0
Est Cost Other
0
Gas Cost In Mcf
3
Prpty
402082
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
876
Gas Flow In Pipe In Mcf
0
Mop Psig
1440
Mop Cfr Section
192.619(A)(1)
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
Automatic
Downstream Valve Type Ind
Manual
Length Segment Isolated
4804
Internal Inspection Ind
Yes
Operation Complications Ind
No
Pipeline Function
Transmission System
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
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
Control room management was not considered a factor in the incident cause or response.
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 Other Corrosion Ind
Yes
Int Corrosion Type Details
Suspected Microbial.
Int Metallurgical Basis Ind
Yes
Int Low Point Pipe Loc Ind
Yes
Corrosion Inhibitors
Yes
Corrosion Lining
No
Cleaning Dewatering
No
Corrosion Coupons
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2024
Hydrtst Most Rcnt Pressure
2193
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
S*** R***
Preparer Title
Pipeline Safety Engineer
Preparer Email
S********@w*******.com
Preparer Telephone
713-449-2720
Local Contact Name
L**** V******
Local Contact Email
L***************@w*******.com
Local Contact Telephone
318-535-8035
Authorizer Name
E*** W****
Authorizer Title
Mgr Pipeline Safety
Authorizer Telephone
281-536-9504
Authorizer Email
E*********@w*******.com
Narrative
On friday afternoon 9/20/24 at 13:21 ct, a technician at the monroe gas storage compressor station observed small bubbles rising within a puddle of water while doing regular inspection rounds within the fenced facility. After confirming the presence of natural gas at the location and suspecting a pinhole leak, the 18" eastside gas transmission line was isolated by manually closing the downstream valves. Because the line was not flowing at the time, the upstream valves were already closed. The effected line segment was isolated by 14:13 ct. After initial coordination regarding possible cost of repair, it was determined to classify the event as an incident and notify the national response center (nrc). The nrc was notified by the williams security operations center at 15:27 ct. The pipeline was safely blown down with lock out / tag out completed by 19:20 ct that evening. Due to the pipeline's 10' depth in the area, it took multiple days for contractors to clean the line through cleaning pigs, purge with nitrogen and pothole through hydrovacing to pinpoint the leak location. Once identified (through detecting the presence of nitrogen), the leak location was fully and safely excavated (considering the significant depth) on 10/14/24. As of 10/15/24, internal corrosion was found at the pinhole leak location. The effected pipe immediately near the leak location was cut-out on 10/17/24 and sent to a lab for analysis. Williams operations, pipeline integrity and construction teams established a conservative plan to replace necessary pipe and return the line to service. Approximately 350 feet of 18-inch pipe in the low area of the pipeline (within the facility) was replaced and hydrotested. The line was returned to service on 11/9/2024. The cause is suspected to be sulfate reducing bacteria microbiologically influenced corrosion (srb-mic) based on lab results. Representatives from operations, management and pipeline integrity have established an internal corrosion mitigation plan to prevent reoccurrence. Coupons have been installed at each well head location and other locations, based on internal corrosion data gathered, operations, management, compliance and corrosion department will deem if more locations are needed. A pigging program that includes all 13 laterals is forthcoming, with additional focus on the 18" lateral.
| Report Received Date | 2024-10-17 00:00:00 |
|---|---|
| Iyear | 2024 |
| Report Number | 20240118 |
| Supplemental Number | 40404 |
| 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 |
| Time Zone | Central |
| Daylight Savings Ind | Yes |
| Location Latitude | 34.01305 Google Maps OpenStreetMap |
| Location Longitude | -88.45674 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1411453 NRC Report How to search |
| Additional Nrc Report Numbers | 1411606 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 164 |
| Intentional Release | 530 |
| 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 |
| Still Shutdown Ind | Yes |
| Communication State Fed Ind | No |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Downstream Action Taken | Valve Closure |
| Num Pub Evacuated | 0 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Ms |
| Onshore Postal Code | 38821 |
| Onshore City Name | Amory |
| Onshore County Name | Monroe |
| Designated Location | Milepost |
| Designated Name | 0.01 |
| Pipe Fac Name | Monroe Gas Storage Facility |
| Segment Name | 18" Eastside Transmission Line |
| 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 | 18 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.375 |
| Pipe Smys | 60000 |
| Pipe Specification | Api 5l Psl2 |
| Pipe Seam Type | Longitudinal Erw - High Frequency |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Epoxy |
| Coating Applied Ind | Yes |
| Installation Year | 2009 |
| Manufactured Year | 2008 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 471 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 492 |
| Est Cost Intentional Release | 1590 |
| Est Cost Prop Damage | 400000 |
| Est Cost Emergency | 0 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 3 |
| Prpty | 402082 |
| 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 | 876 |
| Gas Flow In Pipe In Mcf | 0 |
| Mop Psig | 1440 |
| Mop Cfr Section | 192.619(A)(1) 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 | Automatic |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 4804 |
| Internal Inspection Ind | Yes |
| Operation Complications Ind | No |
| Pipeline Function | Transmission System |
| 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 | 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 | Control room management was not considered a factor in the incident cause or response. |
| 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 Other Corrosion Ind | Yes |
| Int Corrosion Type Details | Suspected Microbial. |
| Int Metallurgical Basis Ind | Yes |
| Int Low Point Pipe Loc Ind | Yes |
| Corrosion Inhibitors | Yes |
| Corrosion Lining | No |
| Cleaning Dewatering | No |
| Corrosion Coupons | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2024 |
| Hydrtst Most Rcnt Pressure | 2193 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | S*** R*** |
| Preparer Title | Pipeline Safety Engineer |
| Preparer Email | S********@w*******.com |
| Preparer Telephone | 713-449-2720 |
| Local Contact Name | L**** V****** |
| Local Contact Email | L***************@w*******.com |
| Local Contact Telephone | 318-535-8035 |
| Authorizer Name | E*** W**** |
| Authorizer Title | Mgr Pipeline Safety |
| Authorizer Telephone | 281-536-9504 |
| Authorizer Email | E*********@w*******.com |
| Narrative | On friday afternoon 9/20/24 at 13:21 ct, a technician at the monroe gas storage compressor station observed small bubbles rising within a puddle of water while doing regular inspection rounds within the fenced facility. After confirming the presence of natural gas at the location and suspecting a pinhole leak, the 18" eastside gas transmission line was isolated by manually closing the downstream valves. Because the line was not flowing at the time, the upstream valves were already closed. The effected line segment was isolated by 14:13 ct. After initial coordination regarding possible cost of repair, it was determined to classify the event as an incident and notify the national response center (nrc). The nrc was notified by the williams security operations center at 15:27 ct. The pipeline was safely blown down with lock out / tag out completed by 19:20 ct that evening. Due to the pipeline's 10' depth in the area, it took multiple days for contractors to clean the line through cleaning pigs, purge with nitrogen and pothole through hydrovacing to pinpoint the leak location. Once identified (through detecting the presence of nitrogen), the leak location was fully and safely excavated (considering the significant depth) on 10/14/24. As of 10/15/24, internal corrosion was found at the pinhole leak location. The effected pipe immediately near the leak location was cut-out on 10/17/24 and sent to a lab for analysis. Williams operations, pipeline integrity and construction teams established a conservative plan to replace necessary pipe and return the line to service. Approximately 350 feet of 18-inch pipe in the low area of the pipeline (within the facility) was replaced and hydrotested. The line was returned to service on 11/9/2024. The cause is suspected to be sulfate reducing bacteria microbiologically influenced corrosion (srb-mic) based on lab results. Representatives from operations, management and pipeline integrity have established an internal corrosion mitigation plan to prevent reoccurrence. Coupons have been installed at each well head location and other locations, based on internal corrosion data gathered, operations, management, compliance and corrosion department will deem if more locations are needed. A pigging program that includes all 13 laterals is forthcoming, with additional focus on the 18" lateral. |
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