Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2022-03-09 — TX
Operator
Natural Gas Pipeline Co Of America (Kmi)
Cause
Equipment Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$0
Incident datetime
2022-03-09 08:15
Report number
Location
TX
Narrative
On 3/09/2022, at 05:43 natural gas pipeline company (ngpl) gas control shut down unit 14 remotely via scada system. Subsequently, ngpl operations specialist received an alarm regarding station 104, unit 14 and started to investigate the cause. At 07:00, operations specialist arrived on site to start troubleshooting the alarm. At 08:15, an operations specialist #2 arrived on site to support mitigate the alarm. Upon arrival was able to hear gas venting through a silencer on unit 14. At 09:59, operations specialist #2 closed the vent valve and called ngpl operations supervisor. At 11:00, operations supervisor arrived on site to investigate the event. At 11:45, the emergency response line (erl) call commenced and during the call, out of abundance of caution ngpl decided to report the event to the nrc from a volume release standpoint. Ngpl started the investigation and concluded that the volume released exceeded the reporting threshold per the compressor unit plc data. The unit 14 suction valve did not close completely after shut down, allowing gas to vent through the vent valve silencer. Furthermore, the investigation also discovered that the suction valve did not close properly due to the limit switches for the valve positioner and the solenoid operator. Ngpl determined that the limit switch that de-energizes the closed solenoid on the valve operator needed to be readjusted. Ngpl e&c tech readjusted the limit switch and cycled the valve numerous times to assure the valve operation. Ngpl put unit 14 back in service the same day. In order to prevent reoccurrence ngpl will be revising the unit plc logic and removing the limit switches in the valve control circuits to the valve control solenoids to avoid interruption of the unit valve open and close signals from the plc.
Detailed record list
Report Received Date
2022-04-07 00:00:00
Iyear
2022
Report Number
20220043
Supplemental Number
36563
Report Type
Original Final
Operator Id
13120
Name
Natural Gas Pipeline Co Of America (Kmi)
Operator Street Address
1001 Louisiana St, Ste 1000
Operator City Name
Houston
Operator State Abbreviation
TX
Operator Postal Code
77002
Local Datetime
2022-03-09 09:04:00
Time Zone
Central
Daylight Savings Ind
Yes
Location Latitude
38.42008
Location Longitude
-98.93069
Nrc Rpt Num
1330611
Nrc Rpt Datetime
2022-03-09 11:56:00
Additional Nrc Report Numbers
1330790
Commodity Released Type
Natural Gas
Unintentional Release
5021
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Status When Identified
Routine Shutdown
Communication State Fed Ind
No
Ignite Ind
No
Num Pub Evacuated
0
Incident Identified Datetime
2022-03-09 08:15:00
On Site Datetime
2022-03-09 07:00:00
On Off Shore
Onshore
Onshore State Abbreviation
Ks
Onshore Postal Code
67530
Onshore City Name
Great Bend
Onshore County Name
Barton
Designated Location
Not Applicable
Pipe Fac Name
Ngpl - Compressor Station 104
Segment Name
Ngpl - Compressor Station 104
Federal
No
Location Type
Operator-Controlled Property
Incident Area Type
Aboveground
Incident Area Subtype
Typical Aboveground Facility Piping Or Appurtenance
Crossing
No
Pipe Facility Type
Interstate
System Part Involved
Onshore Compressor Station Equipment And Piping
Item Involved
Compressor
Installation Year
2010
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Leak
Leak Type
Other
Leak Type Other
Compressor Suction Valve
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
479
Heat Damage Ind
No
Non Heat Damage Ind
No
Did Occur In Mca Ind
No
Est Cost Oper Paid
0
Est Cost Unintentional Release
24402
Est Cost Intentional Release
0
Est Cost Prop Damage
0
Est Cost Emergency
684
Est Cost Other
0
Gas Cost In Mcf
4.86
Prpty
25086
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
195
Gas Flow In Pipe In Mcf
5021
Mop Psig
712
Mop Cfr Section
192.619(A)(2)
Maop Established Date
1991-01-01 00:00:00
Maop Reversal Flow Ind
No
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Gas Required Odorized Ind
No
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
Local Operating Personnel, Including Contractors
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
Incident was deemed independent of the controller(s) actions.
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Equipment Failure
Cause Details
Malfunction Of Control/relief Equipment
Eq Failure Type
Malfunction Of Control/relief Equipment
Instrumentation Ind
Yes
Eq Additional Other Ind
Yes
Eq Additional Other Details
Valve Solenoid Limit Switch Drifted
Preparer Name
J**** L****
Preparer Email
J**********@k***********.com
Preparer Telephone
7134204675
Authorizer Name
J**** H********
Authorizer Telephone
7133699443
Authorizer Email
J**************@k***********.com
Narrative
On 3/09/2022, at 05:43 natural gas pipeline company (ngpl) gas control shut down unit 14 remotely via scada system. Subsequently, ngpl operations specialist received an alarm regarding station 104, unit 14 and started to investigate the cause. At 07:00, operations specialist arrived on site to start troubleshooting the alarm. At 08:15, an operations specialist #2 arrived on site to support mitigate the alarm. Upon arrival was able to hear gas venting through a silencer on unit 14. At 09:59, operations specialist #2 closed the vent valve and called ngpl operations supervisor. At 11:00, operations supervisor arrived on site to investigate the event. At 11:45, the emergency response line (erl) call commenced and during the call, out of abundance of caution ngpl decided to report the event to the nrc from a volume release standpoint. Ngpl started the investigation and concluded that the volume released exceeded the reporting threshold per the compressor unit plc data. The unit 14 suction valve did not close completely after shut down, allowing gas to vent through the vent valve silencer. Furthermore, the investigation also discovered that the suction valve did not close properly due to the limit switches for the valve positioner and the solenoid operator. Ngpl determined that the limit switch that de-energizes the closed solenoid on the valve operator needed to be readjusted. Ngpl e&c tech readjusted the limit switch and cycled the valve numerous times to assure the valve operation. Ngpl put unit 14 back in service the same day. In order to prevent reoccurrence ngpl will be revising the unit plc logic and removing the limit switches in the valve control circuits to the valve control solenoids to avoid interruption of the unit valve open and close signals from the plc.
| Report Received Date | 2022-04-07 00:00:00 |
|---|---|
| Iyear | 2022 |
| Report Number | 20220043 |
| Supplemental Number | 36563 |
| Report Type | Original Final |
| Operator Id | 13120 PHMSA Enforcement |
| Name | Natural Gas Pipeline Co Of America (Kmi) |
| Operator Street Address | 1001 Louisiana St, Ste 1000 |
| Operator City Name | Houston |
| Operator State Abbreviation | TX |
| Operator Postal Code | 77002 |
| Local Datetime | 2022-03-09 09:04:00 |
| Time Zone | Central |
| Daylight Savings Ind | Yes |
| Location Latitude | 38.42008 Google Maps OpenStreetMap |
| Location Longitude | -98.93069 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1330611 NRC Report How to search |
| Nrc Rpt Datetime | 2022-03-09 11:56:00 |
| Additional Nrc Report Numbers | 1330790 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 5021 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Status When Identified | Routine Shutdown |
| Communication State Fed Ind | No |
| Ignite Ind | No |
| Num Pub Evacuated | 0 |
| Incident Identified Datetime | 2022-03-09 08:15:00 |
| On Site Datetime | 2022-03-09 07:00:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Ks |
| Onshore Postal Code | 67530 |
| Onshore City Name | Great Bend |
| Onshore County Name | Barton |
| Designated Location | Not Applicable |
| Pipe Fac Name | Ngpl - Compressor Station 104 |
| Segment Name | Ngpl - Compressor Station 104 |
| Federal | No |
| Location Type | Operator-Controlled Property |
| Incident Area Type | Aboveground |
| Incident Area Subtype | Typical Aboveground Facility Piping Or Appurtenance |
| Crossing | No |
| Pipe Facility Type | Interstate |
| System Part Involved | Onshore Compressor Station Equipment And Piping |
| Item Involved | Compressor |
| Installation Year | 2010 |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Leak |
| Leak Type | Other |
| Leak Type Other | Compressor Suction Valve |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 479 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Did Occur In Mca Ind | No |
| Est Cost Oper Paid | 0 |
| Est Cost Unintentional Release | 24402 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 0 |
| Est Cost Emergency | 684 |
| Est Cost Other | 0 |
| Gas Cost In Mcf | 4.86 |
| Prpty | 25086 |
| 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 | 195 |
| Gas Flow In Pipe In Mcf | 5021 |
| Mop Psig | 712 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Maop Established Date | 1991-01-01 00:00:00 |
| Maop Reversal Flow Ind | No |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Gas Required Odorized Ind | No |
| 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 | Local Operating Personnel, Including Contractors |
| 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 | Incident was deemed independent of the controller(s) actions. |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Equipment Failure |
| Cause Details | Malfunction Of Control/relief Equipment |
| Eq Failure Type | Malfunction Of Control/relief Equipment |
| Instrumentation Ind | Yes |
| Eq Additional Other Ind | Yes |
| Eq Additional Other Details | Valve Solenoid Limit Switch Drifted |
| Preparer Name | J**** L**** |
| Preparer Email | J**********@k***********.com |
| Preparer Telephone | 7134204675 |
| Authorizer Name | J**** H******** |
| Authorizer Telephone | 7133699443 |
| Authorizer Email | J**************@k***********.com |
| Narrative | On 3/09/2022, at 05:43 natural gas pipeline company (ngpl) gas control shut down unit 14 remotely via scada system. Subsequently, ngpl operations specialist received an alarm regarding station 104, unit 14 and started to investigate the cause. At 07:00, operations specialist arrived on site to start troubleshooting the alarm. At 08:15, an operations specialist #2 arrived on site to support mitigate the alarm. Upon arrival was able to hear gas venting through a silencer on unit 14. At 09:59, operations specialist #2 closed the vent valve and called ngpl operations supervisor. At 11:00, operations supervisor arrived on site to investigate the event. At 11:45, the emergency response line (erl) call commenced and during the call, out of abundance of caution ngpl decided to report the event to the nrc from a volume release standpoint. Ngpl started the investigation and concluded that the volume released exceeded the reporting threshold per the compressor unit plc data. The unit 14 suction valve did not close completely after shut down, allowing gas to vent through the vent valve silencer. Furthermore, the investigation also discovered that the suction valve did not close properly due to the limit switches for the valve positioner and the solenoid operator. Ngpl determined that the limit switch that de-energizes the closed solenoid on the valve operator needed to be readjusted. Ngpl e&c tech readjusted the limit switch and cycled the valve numerous times to assure the valve operation. Ngpl put unit 14 back in service the same day. In order to prevent reoccurrence ngpl will be revising the unit plc logic and removing the limit switches in the valve control circuits to the valve control solenoids to avoid interruption of the unit valve open and close signals from the plc. |
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