Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2018-11-17 — OK
Operator
Dominion Energy Questar Pipeline, Llc
Cause
Corrosion Failure
Commodity
Natural Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$462,080
Incident datetime
2018-11-17 18:26
Report number
Location
OK
Narrative
On 11/17/2018 at 18:26 local time, dominion energy questar pipeline's (deqp) main line 048 (ml048) ruptured in rich county, ut. Operators were dispatched and shutdown the ml048 transmission pipeline via manual block valves at 19:47. At 20:12, a deqp operator arrived on-site of the incident and discovered a rupture of the 20" ml048 pipeline which had resulted in an unintended natural gas loss of approximately 48.9 mmscf. Once it was confirmed at 20:48 that the incident was reportable, including confirmation of exact failure location, deqp notified the national response center via telephonic report on 11/17/2018 at 20:53. A 48-hour confirmation of the incident was reported to the nrc on 11/19/2018 at 17:56. An incident investigation team was deployed and progressed an investigation of the failure and repair of the pipeline. Cause of the failure was external corrosion as a result of disbonded coating and cp shielding as determined by a kiefner & associates metallurgical analysis. Notes on particular questions part a: q 6-7. Second nrc notification number 1230856 on 11/19/2018 at 17:56 local time q 15b. Company repaired the pipeline segment directly affected by the failure and placed the segment back in-service subject to several commitments: 1) maintain a pipeline pressure at 80% of operating pressure at time of failure, 2) contract with independent party and complete a pipe failure analysis, 3) complete inline inspection of main line 048 from yellow creek site to the main line 048-main line 060 junction, and 4) perform necessary remediation. The pipe failure analysis has been completed by kiefner and associates. Inline inspection is in progress at the time/date of this supplemental report, and the pipeline remains under the operating restriction commitment (80% of operating pressure at time of failure). Q 19a. Time entered refers to time operator became aware of incident but had not confirmed
Detailed record list
Report Received Date
2018-12-13 00:00:00
Iyear
2018
Report Number
20180129
Supplemental Number
32591
Report Type
Supplemental Final
Operator Id
12874
Name
Dominion Energy Questar Pipeline, Llc
Operator Street Address
One Williams Center
Operator City Name
Tulsa
Operator State Abbreviation
OK
Operator Postal Code
74172
Local Datetime
2018-11-17 18:26:00
Location Latitude
41.42593
Location Longitude
-111.17746
Nrc Rpt Num
1230701
Nrc Rpt Datetime
2018-11-17 20:53:00
Commodity Released Type
Natural Gas
Unintentional Release
48855
Intentional Release
0
Accompanying Liquid
0
Fatality Ind
No
Fatal
0
Injury Ind
No
Injure
0
Shutdown Due Accident Ind
Yes
Shutdown Datetime
2018-11-17 19:47:00
Restart Datetime
2019-01-10 12:30:00
Ignite Ind
No
Explode Ind
No
Num Pub Evacuated
0
Incident Identified Datetime
2018-11-17 18:26:00
On Site Datetime
2018-11-17 20:12:00
On Off Shore
Onshore
Onshore State Abbreviation
Ut
Onshore Postal Code
84086
Onshore City Name
Not Within A Municipality
Onshore County Name
Rich County
Designated Location
Survey Station No.
Designated Name
1933+30.07
Pipe Fac Name
Ml048
Segment Name
Ml048/tl112 Junction To Ml048/jl057 Junction
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Depth Of Cover
43
Crossing
No
Pipe Facility Type
Interstate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
20
Pipe Wall Thickness
0.312
Pipe Smys
42000
Pipe Specification
Api 5l X42
Pipe Seam Type
Longitudinal Erw - High Frequency
Pipe Manufacturer
Us Steel National Duquesne
Pipe Coating Type
Cold Applied Tape
Installation Year
1980
Manufactured Year
1977
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
432
Rupture Width
62.8
Class Location Type
Class 1 Location
Could Be Hca
No
Pir Radius
418
Heat Damage Ind
No
Non Heat Damage Ind
No
Hca Fatalities Ind
No
Est Cost Oper Paid
20000
Est Cost Unintentional Release
118923
Est Cost Intentional Release
0
Est Cost Prop Damage
462080
Est Cost Emergency
21997
Est Cost Other
0
Est Cost Other Details
Estimated Miscellaneous Other Costs.
Prpty
623000
Accident Psig
780
Mop Psig
918
Mop Cfr Section
192.619(A)(2)
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
89232
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
Yes
Scada Conf Ind
Yes
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
It was clear that controller/control room issues were not the cause or a contributing factor
Employee Drug Test Ind
No
Contractor Drug Test Ind
No
Cause
Corrosion Failure
Cause Details
External Corrosion
Internal External
External Corrosion
Visual Exam Results
Localized Pitting
Microbiological Corrosion Ind
Yes
Other Corrosion Ind
Yes
Corrosion Type Details
Kiefner Analysis Concluded That Failure Occurred Due To Corrosion Caused By Disbonded Coating And Cp Shielding
Metallurgical Basis Ind
Yes
Underground Location
Yes
Under Cathodic Protection Ind
Yes
Cathodic Pro Start Year
1980
Shielding Evident
Yes
Cathodic Survey Type
Yes
Cp Annual Survey Ind
Yes
Cp Annual Survey Year
2018
Prior Damage
Yes
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
No
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Preparer Name
C**** B******
Preparer Title
Engineer Ii - Pipeline Compliance
Preparer Email
C**************@d*************.com
Preparer Telephone
8013245117
Authorizer Name
R** J********
Authorizer Title
Vp Western Pipeline Operations
Authorizer Telephone
8013245145
Authorizer Email
R************@d*************.com
Narrative
On 11/17/2018 at 18:26 local time, dominion energy questar pipeline's (deqp) main line 048 (ml048) ruptured in rich county, ut. Operators were dispatched and shutdown the ml048 transmission pipeline via manual block valves at 19:47. At 20:12, a deqp operator arrived on-site of the incident and discovered a rupture of the 20" ml048 pipeline which had resulted in an unintended natural gas loss of approximately 48.9 mmscf. Once it was confirmed at 20:48 that the incident was reportable, including confirmation of exact failure location, deqp notified the national response center via telephonic report on 11/17/2018 at 20:53. A 48-hour confirmation of the incident was reported to the nrc on 11/19/2018 at 17:56. An incident investigation team was deployed and progressed an investigation of the failure and repair of the pipeline. Cause of the failure was external corrosion as a result of disbonded coating and cp shielding as determined by a kiefner & associates metallurgical analysis. Notes on particular questions part a: q 6-7. Second nrc notification number 1230856 on 11/19/2018 at 17:56 local time q 15b. Company repaired the pipeline segment directly affected by the failure and placed the segment back in-service subject to several commitments: 1) maintain a pipeline pressure at 80% of operating pressure at time of failure, 2) contract with independent party and complete a pipe failure analysis, 3) complete inline inspection of main line 048 from yellow creek site to the main line 048-main line 060 junction, and 4) perform necessary remediation. The pipe failure analysis has been completed by kiefner and associates. Inline inspection is in progress at the time/date of this supplemental report, and the pipeline remains under the operating restriction commitment (80% of operating pressure at time of failure). Q 19a. Time entered refers to time operator became aware of incident but had not confirmed
| Report Received Date | 2018-12-13 00:00:00 |
|---|---|
| Iyear | 2018 |
| Report Number | 20180129 |
| Supplemental Number | 32591 |
| Report Type | Supplemental Final |
| Operator Id | 12874 PHMSA Enforcement |
| Name | Dominion Energy Questar Pipeline, Llc |
| Operator Street Address | One Williams Center |
| Operator City Name | Tulsa |
| Operator State Abbreviation | OK |
| Operator Postal Code | 74172 |
| Local Datetime | 2018-11-17 18:26:00 |
| Location Latitude | 41.42593 Google Maps OpenStreetMap |
| Location Longitude | -111.17746 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1230701 NRC Report How to search |
| Nrc Rpt Datetime | 2018-11-17 20:53:00 |
| Commodity Released Type | Natural Gas |
| Unintentional Release | 48855 |
| Intentional Release | 0 |
| Accompanying Liquid | 0 |
| Fatality Ind | No |
| Fatal | 0 |
| Injury Ind | No |
| Injure | 0 |
| Shutdown Due Accident Ind | Yes |
| Shutdown Datetime | 2018-11-17 19:47:00 |
| Restart Datetime | 2019-01-10 12:30:00 |
| Ignite Ind | No |
| Explode Ind | No |
| Num Pub Evacuated | 0 |
| Incident Identified Datetime | 2018-11-17 18:26:00 |
| On Site Datetime | 2018-11-17 20:12:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Ut |
| Onshore Postal Code | 84086 |
| Onshore City Name | Not Within A Municipality |
| Onshore County Name | Rich County |
| Designated Location | Survey Station No. |
| Designated Name | 1933+30.07 |
| Pipe Fac Name | Ml048 |
| Segment Name | Ml048/tl112 Junction To Ml048/jl057 Junction |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Depth Of Cover | 43 |
| Crossing | No |
| Pipe Facility Type | Interstate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 20 |
| Pipe Wall Thickness | 0.312 |
| Pipe Smys | 42000 |
| Pipe Specification | Api 5l X42 |
| Pipe Seam Type | Longitudinal Erw - High Frequency |
| Pipe Manufacturer | Us Steel National Duquesne |
| Pipe Coating Type | Cold Applied Tape |
| Installation Year | 1980 |
| Manufactured Year | 1977 |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 432 |
| Rupture Width | 62.8 |
| Class Location Type | Class 1 Location |
| Could Be Hca | No |
| Pir Radius | 418 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Hca Fatalities Ind | No |
| Est Cost Oper Paid | 20000 |
| Est Cost Unintentional Release | 118923 |
| Est Cost Intentional Release | 0 |
| Est Cost Prop Damage | 462080 |
| Est Cost Emergency | 21997 |
| Est Cost Other | 0 |
| Est Cost Other Details | Estimated Miscellaneous Other Costs. |
| Prpty | 623000 |
| Accident Psig | 780 |
| Mop Psig | 918 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 89232 |
| 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 | Yes |
| Scada Conf Ind | Yes |
| 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 | It was clear that controller/control room issues were not the cause or a contributing factor |
| Employee Drug Test Ind | No |
| Contractor Drug Test Ind | No |
| Cause | Corrosion Failure |
| Cause Details | External Corrosion |
| Internal External | External Corrosion |
| Visual Exam Results | Localized Pitting |
| Microbiological Corrosion Ind | Yes |
| Other Corrosion Ind | Yes |
| Corrosion Type Details | Kiefner Analysis Concluded That Failure Occurred Due To Corrosion Caused By Disbonded Coating And Cp Shielding |
| Metallurgical Basis Ind | Yes |
| Underground Location | Yes |
| Under Cathodic Protection Ind | Yes |
| Cathodic Pro Start Year | 1980 |
| Shielding Evident | Yes |
| Cathodic Survey Type | Yes |
| Cp Annual Survey Ind | Yes |
| Cp Annual Survey Year | 2018 |
| Prior Damage | Yes |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | No |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Preparer Name | C**** B****** |
| Preparer Title | Engineer Ii - Pipeline Compliance |
| Preparer Email | C**************@d*************.com |
| Preparer Telephone | 8013245117 |
| Authorizer Name | R** J******** |
| Authorizer Title | Vp Western Pipeline Operations |
| Authorizer Telephone | 8013245145 |
| Authorizer Email | R************@d*************.com |
| Narrative | On 11/17/2018 at 18:26 local time, dominion energy questar pipeline's (deqp) main line 048 (ml048) ruptured in rich county, ut. Operators were dispatched and shutdown the ml048 transmission pipeline via manual block valves at 19:47. At 20:12, a deqp operator arrived on-site of the incident and discovered a rupture of the 20" ml048 pipeline which had resulted in an unintended natural gas loss of approximately 48.9 mmscf. Once it was confirmed at 20:48 that the incident was reportable, including confirmation of exact failure location, deqp notified the national response center via telephonic report on 11/17/2018 at 20:53. A 48-hour confirmation of the incident was reported to the nrc on 11/19/2018 at 17:56. An incident investigation team was deployed and progressed an investigation of the failure and repair of the pipeline. Cause of the failure was external corrosion as a result of disbonded coating and cp shielding as determined by a kiefner & associates metallurgical analysis. Notes on particular questions part a: q 6-7. Second nrc notification number 1230856 on 11/19/2018 at 17:56 local time q 15b. Company repaired the pipeline segment directly affected by the failure and placed the segment back in-service subject to several commitments: 1) maintain a pipeline pressure at 80% of operating pressure at time of failure, 2) contract with independent party and complete a pipe failure analysis, 3) complete inline inspection of main line 048 from yellow creek site to the main line 048-main line 060 junction, and 4) perform necessary remediation. The pipe failure analysis has been completed by kiefner and associates. Inline inspection is in progress at the time/date of this supplemental report, and the pipeline remains under the operating restriction commitment (80% of operating pressure at time of failure). Q 19a. Time entered refers to time operator became aware of incident but had not confirmed |
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