Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2023-04-24 — NE
Operator
Northern Natural Gas Co
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$595,000
Incident datetime
2023-04-24 00:00 UTC
Report number
Location
NE
Narrative
An aerial survey using lidar detected and was confirmed by field personnel on march 30, 2023. The pipeline segment was isolated and pressure was reduced using both compression and flaring gas from the isolated segment. A larger volume flaring assembly was brought in on april 2 after the initial flaring equipment was not as effective as desired. Excavation and preliminary evaluation concluded on april 3, 2023, and general corrosion believed to be caused by microbiological and disbonded coating. A cylinder of pipe replaced the location of corrosion and the removed section was sent to a lab for further examination. Metallurgical analysis identified that the leak was in the center of external surface that contained pitting most severally concentrated in a 24-inch by 26-inch area. The leak being through wall corrosion with 90% to 100% wall loss in circular form. Soil product samples support microbiological corrosion. No pitting or corrosion damage to the internal surface of the internal epoxy coating noted except damage at the thru wall leak location.
Detailed record list
Report Received Date
2023-04-24 00:00:00
Iyear
2023
Report Number
20230037
Supplemental Number
38101
Report Type
Supplemental Final
Operator Id
13750
Name
Northern Natural Gas Co
Operator Street Address
1111 South 103rd Street
Operator City Name
Omaha
Operator State Abbreviation
NE
Operator Postal Code
68124
Time Zone
Central
Daylight Savings Ind
No
Location Latitude
39.6027417
Location Longitude
-97.2158317
Nrc Rpt Num
1363826
Additional Nrc Report Numbers
1363937
Commodity Released Type
Natural Gas
Unintentional Release
1790
Intentional Release
17055
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
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Ignite Ind
No
Upstream Action Taken
Valve Closure
Downstream Action Taken
Valve Closure
Num Pub Evacuated
0
On Off Shore
Onshore
Onshore State Abbreviation
Ks
Onshore Postal Code
66937
Onshore City Name
Not Within A Municipality
Onshore County Name
Washington
Designated Location
Milepost
Designated Name
4.34
Pipe Fac Name
Clifton To Beatrice E-Line
Segment Name
M600e
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
48
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
30
Puddle Weld Ind
No
Pipe Wall Thickness
0.344
Pipe Smys
60000
Pipe Specification
Api 5lx
Pipe Seam Type
Longitudinal Erw - Unknown Frequency
Pipe Manufacturer
Ao Smith
Pipe Coating Type
Coal Tar
Coating Applied Ind
Unknown
Installation Year
1963
Manufactured Year
1963
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Pinhole
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
690
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
850
Est Cost Unintentional Release
3741
Est Cost Intentional Release
35645
Est Cost Prop Damage
595000
Est Cost Emergency
53000
Est Cost Other
0
Gas Cost In Mcf
2.09
Prpty
688236
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
880
Gas Flow In Pipe In Mcf
583
Mop Psig
991
Mop Cfr Section
192.619(A)(2)
Maop Established Date
1963-12-01 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
Remotely Controlled
Downstream Valve Type Ind
Manual
Length Segment Isolated
104966
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
Air Patrol
Operator Type
Contractor Working For The Operator
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
External Corrosion
Internal External
External Corrosion
Visual Exam Results
General Corrosion
Microbiological Corrosion Ind
Yes
Field Exam Basis Ind
Yes
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
1963
Shielding Evident
Yes
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Close Interval Survey Ind
Yes
Cp Annual Survey Year
2023
Close Interval Survey Year
2023
Prior Damage
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Extrnl Cor Microbiologic Ind
Yes
Preparer Name
D**** C*******
Preparer Title
Sr. Engineer Ii
Preparer Email
D*************@n****.com
Preparer Telephone
4023987439
Preparer Fax
4025485267
Authorizer Name
T** C******
Authorizer Title
Vice President Of Pipeline Safety And Risk
Authorizer Telephone
4023987715
Authorizer Email
T*************@n****.com
Narrative
An aerial survey using lidar detected and was confirmed by field personnel on march 30, 2023. The pipeline segment was isolated and pressure was reduced using both compression and flaring gas from the isolated segment. A larger volume flaring assembly was brought in on april 2 after the initial flaring equipment was not as effective as desired. Excavation and preliminary evaluation concluded on april 3, 2023, and general corrosion believed to be caused by microbiological and disbonded coating. A cylinder of pipe replaced the location of corrosion and the removed section was sent to a lab for further examination. Metallurgical analysis identified that the leak was in the center of external surface that contained pitting most severally concentrated in a 24-inch by 26-inch area. The leak being through wall corrosion with 90% to 100% wall loss in circular form. Soil product samples support microbiological corrosion. No pitting or corrosion damage to the internal surface of the internal epoxy coating noted except damage at the thru wall leak location.
| Report Received Date | 2023-04-24 00:00:00 |
|---|---|
| Iyear | 2023 |
| Report Number | 20230037 |
| Supplemental Number | 38101 |
| Report Type | Supplemental Final |
| Operator Id | 13750 PHMSA Enforcement |
| Name | Northern Natural Gas Co |
| Operator Street Address | 1111 South 103rd Street |
| Operator City Name | Omaha |
| Operator State Abbreviation | NE |
| Operator Postal Code | 68124 |
| Time Zone | Central |
| Daylight Savings Ind | No |
| Location Latitude | 39.6027417 Google Maps OpenStreetMap |
| Location Longitude | -97.2158317 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1363826 NRC Report How to search |
| Additional Nrc Report Numbers | 1363937 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 1790 |
| Intentional Release | 17055 |
| 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 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Ignite Ind | No |
| Upstream Action Taken | Valve Closure |
| Downstream Action Taken | Valve Closure |
| Num Pub Evacuated | 0 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Ks |
| Onshore Postal Code | 66937 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Washington |
| Designated Location | Milepost |
| Designated Name | 4.34 |
| Pipe Fac Name | Clifton To Beatrice E-Line |
| Segment Name | M600e |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 48 |
| 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 | 30 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.344 |
| Pipe Smys | 60000 |
| Pipe Specification | Api 5lx |
| Pipe Seam Type | Longitudinal Erw - Unknown Frequency |
| Pipe Manufacturer | Ao Smith |
| Pipe Coating Type | Coal Tar |
| Coating Applied Ind | Unknown |
| Installation Year | 1963 |
| Manufactured Year | 1963 |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Pinhole |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 690 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 850 |
| Est Cost Unintentional Release | 3741 |
| Est Cost Intentional Release | 35645 |
| Est Cost Prop Damage | 595000 |
| Est Cost Emergency | 53000 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 2.09 |
| Prpty | 688236 |
| 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 | 880 |
| Gas Flow In Pipe In Mcf | 583 |
| Mop Psig | 991 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Maop Established Date | 1963-12-01 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 | Remotely Controlled |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 104966 |
| 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 | Air Patrol |
| Operator Type | Contractor Working For The Operator |
| 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 | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | General Corrosion |
| Microbiological Corrosion Ind | Yes |
| Field Exam Basis Ind | Yes |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 1963 |
| Shielding Evident | Yes |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Close Interval Survey Ind | Yes |
| Cp Annual Survey Year | 2023 |
| Close Interval Survey Year | 2023 |
| Prior Damage | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Extrnl Cor Microbiologic Ind | Yes |
| Preparer Name | D**** C******* |
| Preparer Title | Sr. Engineer Ii |
| Preparer Email | D*************@n****.com |
| Preparer Telephone | 4023987439 |
| Preparer Fax | 4025485267 |
| Authorizer Name | T** C****** |
| Authorizer Title | Vice President Of Pipeline Safety And Risk |
| Authorizer Telephone | 4023987715 |
| Authorizer Email | T*************@n****.com |
| Narrative | An aerial survey using lidar detected and was confirmed by field personnel on march 30, 2023. The pipeline segment was isolated and pressure was reduced using both compression and flaring gas from the isolated segment. A larger volume flaring assembly was brought in on april 2 after the initial flaring equipment was not as effective as desired. Excavation and preliminary evaluation concluded on april 3, 2023, and general corrosion believed to be caused by microbiological and disbonded coating. A cylinder of pipe replaced the location of corrosion and the removed section was sent to a lab for further examination. Metallurgical analysis identified that the leak was in the center of external surface that contained pitting most severally concentrated in a 24-inch by 26-inch area. The leak being through wall corrosion with 90% to 100% wall loss in circular form. Soil product samples support microbiological corrosion. No pitting or corrosion damage to the internal surface of the internal epoxy coating noted except damage at the thru wall leak location. |
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