Incident details
Operator, cause, commodity and consequences with raw source fields.
GTG incident on 2020-02-17 — CO
Operator
Markwest Javelina Pipeline Company, L.l.c.
Cause
Corrosion Failure
Commodity
Other Gas
Program
GTG
Damage and Injuries
0 fatalities
0 injuries
Property damage (nominal)
$260,000
Incident datetime
2020-02-17 10:09
Report number
Location
CO
Narrative
A fire ignited at the intersection of buddy lawrence and i37 frontage road at mile marker 1e. With the amount of pipelines in the area and congestion it was difficult at first to identify who's pipeline was leaking. With such low pressures on our rg pipelines it can be difficult to see drastic pressure interruptions. In the process of isolation we were able to 100% commit to the leak being our pipeline. In the investigation the cause of the incident has been determined to be internal corrosion. Upon a visual examination, localized pitting was discovered that has been attributed to differential aeration produced by the deposits which collected on the bottom of the pipeline. The collection of these deposits likely exacerbated by the low volume and/or flow rates. The entire east side system of the system including the rg-800 has been put through a rigorous cleaning regime, and pressure tested to show the integrity of the line to 433 psig. This was only done after multiple failed attempts to smart tool the line, due to the line not being peggable although we did spend countless resources on trying to make the system smart piggable. This pipeline contains multiple tight bends that did not allow the passing of the smart tools. Investigation has not shown any indication of general corrosion along the entire system, but showed to be localized to the area that failed.
Detailed record list
Report Received Date
2020-03-16 00:00:00
Iyear
2020
Report Number
20200022
Supplemental Number
33807
Report Type
Supplemental Final
Operator Id
9171
Name
Markwest Javelina Pipeline Company, L.l.c.
Operator Street Address
1515 Arapahoe Street Tower 1, Suite 1600
Operator City Name
Denver
Operator State Abbreviation
CO
Operator Postal Code
80202
Local Datetime
2020-02-17 10:09:00
Time Zone
Central
Daylight Savings Ind
No
Location Latitude
27.80297
Location Longitude
-97.430534
Nrc Rpt Num
1271395
Nrc Rpt Datetime
2020-02-17 09:21:00
Commodity Released Type
Other Gas
Commodity Details
Refinery Off Gas (Raw Gas)
Unintentional Release
2598
Intentional Release
161
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
2020-02-17 10:03:00
Restart Datetime
2020-04-25 11:00:00
Communication State Fed Ind
Yes
Party Initiated Communication
Operator
Initial Responder Com Datetime
2020-02-17 08:37:00
Ignite Ind
Yes
Ignite Datetime
2020-02-17 08:35:00
How Extinguished
Other
How Extinguished Other Detail
Once We Isolated The Gas To The Pipeline The Fired Burned Out
Gas Consumed By Fire In Mcf
2280
Explode Ind
Yes
Upstream Action Taken
Valve Closure
Upstream Valve Close Datetime
2020-02-17 09:55:00
Downstream Action Taken
Valve Closure
Downstream Vlv Close Datetime
2020-02-17 10:02:00
Num Pub Evacuated
10
Incident Identified Datetime
2020-02-17 10:09:00
On Site Datetime
2020-02-17 08:45:00
On Off Shore
Onshore
Onshore State Abbreviation
Tx
Onshore Postal Code
78408
Onshore City Name
Corpus Christi
Onshore County Name
Nueces
Designated Location
Milepost
Designated Name
I37 Exit 1e
Pipe Fac Name
Javelina
Segment Name
Rg-800
Federal
No
Location Type
Pipeline Right-Of-Way
Incident Area Type
Underground
Incident Area Subtype
Under Soil
Other Underground Facilities
No
Crossing
No
Pipe Facility Type
Intrastate
System Part Involved
Onshore Pipeline, Including Valve Sites
Item Involved
Pipe
Pipe Type
Pipe Body
Pipe Diameter
20
Puddle Weld Ind
No
Pipe Wall Thickness
0.25
Pipe Smys
35000
Pipe Specification
Grade B
Pipe Seam Type
Longitudinal Erw - High Frequency
Pipe Manufacturer
Unknown
Pipe Coating Type
Epoxy
Coating Applied Ind
No
Installation Year
1990
Manufactured Year
Unknown
Material Involved
Carbon Steel
Release Type
Rupture
Rupture Orient
Longitudinal
Rupture Length
74.5
Rupture Width
3.7
Class Location Type
Class 3 Location
Could Be Hca
No
Pir Radius
226
Heat Damage Ind
No
Non Heat Damage Ind
No
Est Cost Oper Paid
320000
Est Cost Unintentional Release
6482
Est Cost Intentional Release
402
Est Cost Prop Damage
260000
Est Cost Emergency
75000
Est Cost Other
2650000
Est Cost Other Details
7.d - Pipeline Cleaning, Ili Attempts, Hydro-Testing
Gas Cost In Mcf
2.495
Prpty
3311884
Num Persons Hosp Not Ovnght
0
Num Injured Treated By Emt
0
Num Resident Building Affctd
0
Num Business Building Affctd
1
Wildlife Impact Ind
No
Accident Psig
55
Gas Flow In Pipe In Mcf
11100
Mop Psig
240
Mop Cfr Section
192.619(A)(2)
Maop Established Date
1990-08-21 00:00:00
Maop Reversal Flow Ind
No
Accident Pressure
Pressure Did Not Exceed Maop
Pressure Restriction Ind
No
Gas Required Odorized Ind
No
Gas Odorized Ind
Yes
Upstream Valve Type Ind
Manual
Downstream Valve Type Ind
Manual
Length Segment Isolated
1062
Internal Inspection Ind
No
Tight Mitered Ind
Yes
Other Restrictions Ind
Yes
Other Inspection Ind
Yes
Internal Inspection Details
Line Was Designed To Run Maintenance Pigs From The 20" To A 24", Not Smart Tools. There Are Tight Back To Back 90's As Well As No Receiver On The 20" (Rg-800).
Operation Complications Ind
Yes
Excessive Debris Ind
Yes
Low Op Pressure Ind
Yes
Low Flow Ind
Yes
Other Complications Ind
Yes
Inspect Comp Details
Tight Radius Bends
Pipeline Function
Transmission System
Scada In Place Ind
Yes
Scada Operating Ind
Yes
Scada Functional Ind
Yes
Scada Detection Ind
No
Scada Conf Ind
Yes
Accident Identifier
Local Operating Personnel, Including Contractors
Operator Type
Operator Employee
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
Invest Other Ind
Yes
Invest Other Ind Details
Markwest Identified That Additional Alarms Or Pressure Indicators Would Help In Identifying Pressure Increases Or Decreases At Off-Sites.
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 Microbiological Ind
Yes
Int Other Corrosion Ind
Yes
Int Corrosion Type Details
Differential Aeration Produced By The Deposits Which Collected On The Bottom Of The Pipe. The Collection Of These Deposits Was Likely Exacerbated By The Low Volume And/or Flow Rates.
Int Metallurgical Basis Ind
Yes
Int Low Point Pipe Loc Ind
Yes
Corrosion Inhibitors
No
Corrosion Lining
No
Cleaning Dewatering
No
Corrosion Coupons
No
Collected Data Ind
No
Has Hydrtst Conduc Before Ind
Yes
Hydrtst Most Rcnt Year
2019
Hydrtst Most Rcnt Pressure
172
Direct Asmnt Conducted
No
Non Destructive Exam Ind
No
Intrnl Cor Microbiologic Ind
Yes
Preparer Name
T*** M********
Preparer Title
Pipeline Compliance Supervisor
Preparer Email
T*********@m***.com
Preparer Telephone
303-489-3275
Local Contact Name
K**** T*******
Local Contact Email
K*********@m***.com
Local Contact Telephone
(361) 289-4755
Authorizer Name
D***** T******
Authorizer Title
Engineering Mgr
Authorizer Telephone
(303) 531-9089
Authorizer Email
D*******@m***.com
Narrative
A fire ignited at the intersection of buddy lawrence and i37 frontage road at mile marker 1e. With the amount of pipelines in the area and congestion it was difficult at first to identify who's pipeline was leaking. With such low pressures on our rg pipelines it can be difficult to see drastic pressure interruptions. In the process of isolation we were able to 100% commit to the leak being our pipeline. In the investigation the cause of the incident has been determined to be internal corrosion. Upon a visual examination, localized pitting was discovered that has been attributed to differential aeration produced by the deposits which collected on the bottom of the pipeline. The collection of these deposits likely exacerbated by the low volume and/or flow rates. The entire east side system of the system including the rg-800 has been put through a rigorous cleaning regime, and pressure tested to show the integrity of the line to 433 psig. This was only done after multiple failed attempts to smart tool the line, due to the line not being peggable although we did spend countless resources on trying to make the system smart piggable. This pipeline contains multiple tight bends that did not allow the passing of the smart tools. Investigation has not shown any indication of general corrosion along the entire system, but showed to be localized to the area that failed.
| Report Received Date | 2020-03-16 00:00:00 |
|---|---|
| Iyear | 2020 |
| Report Number | 20200022 |
| Supplemental Number | 33807 |
| Report Type | Supplemental Final |
| Operator Id | 9171 PHMSA Enforcement |
| Name | Markwest Javelina Pipeline Company, L.l.c. |
| Operator Street Address | 1515 Arapahoe Street Tower 1, Suite 1600 |
| Operator City Name | Denver |
| Operator State Abbreviation | CO |
| Operator Postal Code | 80202 |
| Local Datetime | 2020-02-17 10:09:00 |
| Time Zone | Central |
| Daylight Savings Ind | No |
| Location Latitude | 27.80297 Google Maps OpenStreetMap |
| Location Longitude | -97.430534 Google Maps OpenStreetMap |
| Nrc Rpt Num | 1271395 NRC Report How to search |
| Nrc Rpt Datetime | 2020-02-17 09:21:00 |
| Commodity Released Type | Other Gas |
| Commodity Details | Refinery Off Gas (Raw Gas) |
| Unintentional Release | 2598 |
| Intentional Release | 161 |
| 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 | 2020-02-17 10:03:00 |
| Restart Datetime | 2020-04-25 11:00:00 |
| Communication State Fed Ind | Yes |
| Party Initiated Communication | Operator |
| Initial Responder Com Datetime | 2020-02-17 08:37:00 |
| Ignite Ind | Yes |
| Ignite Datetime | 2020-02-17 08:35:00 |
| How Extinguished | Other |
| How Extinguished Other Detail | Once We Isolated The Gas To The Pipeline The Fired Burned Out |
| Gas Consumed By Fire In Mcf | 2280 |
| Explode Ind | Yes |
| Upstream Action Taken | Valve Closure |
| Upstream Valve Close Datetime | 2020-02-17 09:55:00 |
| Downstream Action Taken | Valve Closure |
| Downstream Vlv Close Datetime | 2020-02-17 10:02:00 |
| Num Pub Evacuated | 10 |
| Incident Identified Datetime | 2020-02-17 10:09:00 |
| On Site Datetime | 2020-02-17 08:45:00 |
| On Off Shore | Onshore |
| Onshore State Abbreviation | Tx |
| Onshore Postal Code | 78408 |
| Onshore City Name | Corpus Christi |
| Onshore County Name | Nueces |
| Designated Location | Milepost |
| Designated Name | I37 Exit 1e |
| Pipe Fac Name | Javelina |
| Segment Name | Rg-800 |
| Federal | No |
| Location Type | Pipeline Right-Of-Way |
| Incident Area Type | Underground |
| Incident Area Subtype | Under Soil |
| Other Underground Facilities | No |
| Crossing | No |
| Pipe Facility Type | Intrastate |
| System Part Involved | Onshore Pipeline, Including Valve Sites |
| Item Involved | Pipe |
| Pipe Type | Pipe Body |
| Pipe Diameter | 20 |
| Puddle Weld Ind | No |
| Pipe Wall Thickness | 0.25 |
| Pipe Smys | 35000 |
| Pipe Specification | Grade B |
| Pipe Seam Type | Longitudinal Erw - High Frequency |
| Pipe Manufacturer | Unknown |
| Pipe Coating Type | Epoxy |
| Coating Applied Ind | No |
| Installation Year | 1990 |
| Manufactured Year | Unknown |
| Material Involved | Carbon Steel |
| Release Type | Rupture |
| Rupture Orient | Longitudinal |
| Rupture Length | 74.5 |
| Rupture Width | 3.7 |
| Class Location Type | Class 3 Location |
| Could Be Hca | No |
| Pir Radius | 226 |
| Heat Damage Ind | No |
| Non Heat Damage Ind | No |
| Est Cost Oper Paid | 320000 |
| Est Cost Unintentional Release | 6482 |
| Est Cost Intentional Release | 402 |
| Est Cost Prop Damage | 260000 |
| Est Cost Emergency | 75000 |
| Est Cost Other | 2650000 |
| Est Cost Other Details | 7.d - Pipeline Cleaning, Ili Attempts, Hydro-Testing |
| Gas Cost In Mcf | 2.495 |
| Prpty | 3311884 |
| Num Persons Hosp Not Ovnght | 0 |
| Num Injured Treated By Emt | 0 |
| Num Resident Building Affctd | 0 |
| Num Business Building Affctd | 1 |
| Wildlife Impact Ind | No |
| Accident Psig | 55 |
| Gas Flow In Pipe In Mcf | 11100 |
| Mop Psig | 240 |
| Mop Cfr Section | 192.619(A)(2) View CFR 49 §192 |
| Maop Established Date | 1990-08-21 00:00:00 |
| Maop Reversal Flow Ind | No |
| Accident Pressure | Pressure Did Not Exceed Maop |
| Pressure Restriction Ind | No |
| Gas Required Odorized Ind | No |
| Gas Odorized Ind | Yes |
| Upstream Valve Type Ind | Manual |
| Downstream Valve Type Ind | Manual |
| Length Segment Isolated | 1062 |
| Internal Inspection Ind | No |
| Tight Mitered Ind | Yes |
| Other Restrictions Ind | Yes |
| Other Inspection Ind | Yes |
| Internal Inspection Details | Line Was Designed To Run Maintenance Pigs From The 20" To A 24", Not Smart Tools. There Are Tight Back To Back 90's As Well As No Receiver On The 20" (Rg-800). |
| Operation Complications Ind | Yes |
| Excessive Debris Ind | Yes |
| Low Op Pressure Ind | Yes |
| Low Flow Ind | Yes |
| Other Complications Ind | Yes |
| Inspect Comp Details | Tight Radius Bends |
| Pipeline Function | Transmission System |
| Scada In Place Ind | Yes |
| Scada Operating Ind | Yes |
| Scada Functional Ind | Yes |
| Scada Detection Ind | No |
| Scada Conf Ind | Yes |
| Accident Identifier | Local Operating Personnel, Including Contractors |
| Operator Type | Operator Employee |
| 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 |
| Invest Other Ind | Yes |
| Invest Other Ind Details | Markwest Identified That Additional Alarms Or Pressure Indicators Would Help In Identifying Pressure Increases Or Decreases At Off-Sites. |
| 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 Microbiological Ind | Yes |
| Int Other Corrosion Ind | Yes |
| Int Corrosion Type Details | Differential Aeration Produced By The Deposits Which Collected On The Bottom Of The Pipe. The Collection Of These Deposits Was Likely Exacerbated By The Low Volume And/or Flow Rates. |
| Int Metallurgical Basis Ind | Yes |
| Int Low Point Pipe Loc Ind | Yes |
| Corrosion Inhibitors | No |
| Corrosion Lining | No |
| Cleaning Dewatering | No |
| Corrosion Coupons | No |
| Collected Data Ind | No |
| Has Hydrtst Conduc Before Ind | Yes |
| Hydrtst Most Rcnt Year | 2019 |
| Hydrtst Most Rcnt Pressure | 172 |
| Direct Asmnt Conducted | No |
| Non Destructive Exam Ind | No |
| Intrnl Cor Microbiologic Ind | Yes |
| Preparer Name | T*** M******** |
| Preparer Title | Pipeline Compliance Supervisor |
| Preparer Email | T*********@m***.com |
| Preparer Telephone | 303-489-3275 |
| Local Contact Name | K**** T******* |
| Local Contact Email | K*********@m***.com |
| Local Contact Telephone | (361) 289-4755 |
| Authorizer Name | D***** T****** |
| Authorizer Title | Engineering Mgr |
| Authorizer Telephone | (303) 531-9089 |
| Authorizer Email | D*******@m***.com |
| Narrative | A fire ignited at the intersection of buddy lawrence and i37 frontage road at mile marker 1e. With the amount of pipelines in the area and congestion it was difficult at first to identify who's pipeline was leaking. With such low pressures on our rg pipelines it can be difficult to see drastic pressure interruptions. In the process of isolation we were able to 100% commit to the leak being our pipeline. In the investigation the cause of the incident has been determined to be internal corrosion. Upon a visual examination, localized pitting was discovered that has been attributed to differential aeration produced by the deposits which collected on the bottom of the pipeline. The collection of these deposits likely exacerbated by the low volume and/or flow rates. The entire east side system of the system including the rg-800 has been put through a rigorous cleaning regime, and pressure tested to show the integrity of the line to 433 psig. This was only done after multiple failed attempts to smart tool the line, due to the line not being peggable although we did spend countless resources on trying to make the system smart piggable. This pipeline contains multiple tight bends that did not allow the passing of the smart tools. Investigation has not shown any indication of general corrosion along the entire system, but showed to be localized to the area that failed. |
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