Best Practice for Management of Pipeline Integrity …...Operational pigging Management of internal...
Transcript of Best Practice for Management of Pipeline Integrity …...Operational pigging Management of internal...
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Best Practice for Management of Pipeline Integrity by Pigging
12th February 2015
Paul OtwaySenior Subsea Engineer, Jee Limited
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Agenda
Pigging: What, why and when?Pipeline inspection by MFL toolsPipeline inspection by UT toolsILI tool selection
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What is ILI and why use it?
In-line inspection• Method of collecting wall thickness or metal loss data to enable
assessment of pipeline fitness for purpose
ILI can provide information on• General and local wall thickness / metal loss• Corrosion• Cracks• Laminations• Weld defects
Best practice for management of pipeline condition• Often in conjunction with operational pigging
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Operational pigging
Management of internal condition to reduce riskSphering• Liquid sweep in gas lines• Spreading inhibitors
Cleaning• Removal of debris e.g. wax
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When to do ILI?In
stal
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Design operational life
Ext
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Start-upEnd of
design life
Baseline inspection
Regular re-inspection (frequency is risk-based)
Validation for lifetime extension
Dec
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Re-validation
End of use
Operational pigging throughout lifecycle if required
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Pipeline piggability
Not all pipelines are suitable for piggingAvailability of suitable facilities and pig traps is criticalBore range• Single diameter preferable• Multi-diameter lines can be piggable, often need bespoke tools
Minimum bend radii• 5D preferred• 3D possible with most tools• 1.5D possible with a few tools
Pipeline features and restrictions• Back to back bends• Valves• Offtakes (tees & wyes)
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Agenda
Pigging: What, why and when?Pipeline inspection by MFL toolsPipeline inspection by UT toolsILI tool selection
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Magnetic flux leakage (MFL) tools
16” PII MFL tool
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Principle of operation
Brush
MagnetSensor
Brush
Magnet
Brush
MagnetSensor
Brush
Magnet
No defect present
Defect presentDefect
Leakage of field
N
N S
S
Section of pipe wall
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Output interpretation
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Agenda
ILI: What, why and when?Pipeline inspection by MFL toolsPipeline inspection by UT toolsILI tool selection
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Ultrasonic technology (UT) tools
12” NDT ultrasonic ILI tool
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Principle of operation
Diagram courtesy of NDT Systems & Services
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Output interpretation
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Agenda
Pigging: What, why and when?Pipeline inspection by MFL toolsPipeline inspection by UT toolsILI technology selection
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Operational constraints
What is the available drive medium?• UT – needs liquid couplant• MFL – can operate in gas or liquid
What are the process conditions during pigging and how controllable are they?• Flowrate
• UT – requires low, controlled flowrate (c. 0.5 – 1.0 m/s)• MFL – can tolerate higher flowrates and fluctuation (up to 4.0 m/s)
• Pressure• UT and MFL – most tools c. 120-150 bar, some up to 300-400 bar
• Temperature• UT and MFL – most operate up to c. 65°C
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Defect detection requirements
What is the pipeline construction?• MFL – can only magnetise carbon steel lines• UT – can measure wall loss in most materials (CS, duplex, CRA)
What are the specific degradation mechanisms and threats to the pipeline?• Global metal loss – MFL or UT generally suitable• Pitting – UT provides higher resolution data• Cracking – specific tool setup required whether UT or MFL
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Scope of inspection
What sections of the pipeline can be inspected?• Full pipeline from trap to trap
• Traditional MFL or UT tool suitable• Local riser/spools only
• Crawler tool (usually UT)• Bi-directional ILI tool (MFL or UT)
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Thank you for listening
Paul Otway
Best Practice for Management of Pipeline Integrity by Pigging