Pipeline failure statistics are consistent across regions. External interference, external corrosion, internal corrosion, material and construction defects, and ground movement account for the great majority of incidents. Each of these is addressed by a specific engineering control: depth of cover, marking and surveillance for interference; coating and cathodic protection for external corrosion; inhibition, dehydration and pigging for internal corrosion; construction quality control and hydrotest for defects; and route selection and monitoring for ground movement. Integrity management is the systematic application of these controls with verification that they are working.

The verification is where in-line inspection matters. A pipeline gives almost no warning of deterioration from the outside, so its condition is established by running instrumented tools through it. Magnetic flux leakage and ultrasonic tools detect metal loss, geometry tools detect deformation, and crack detection tools address a specific and dangerous threat. Interpreting the output requires understanding the tool's detection threshold, sizing accuracy and limitations, and assessing the reported features against a defect assessment method before deciding whether the line can continue to operate at pressure.

Hydraulic design has consequences that persist for the pipeline's life. Line size determines throughput and the pressure the system must generate. Pump or compressor station spacing determines energy consumption. Surge behaviour determines whether the line can be shut down rapidly without exceeding design pressure. For multi-product lines, the interface behaviour between batches determines how much product is downgraded on every transfer.

Finally, pipelines are operated remotely, which places unusual weight on measurement and leak detection. A control room operator sees flow, pressure and temperature at a small number of points and infers the condition of hundreds of kilometres between them. Understanding the sensitivity and limitations of leak detection methods, and the operating discipline that supports them, is a core competence for anyone responsible for pipeline operations.

By the end of this training, participants will be able to:

• Identify the design codes applicable to liquid and gas pipelines and apply design factor and location class requirements
• Calculate pipeline wall thickness for internal pressure and assess external pressure and installation loads
• Evaluate route selection, crossing design, depth of cover and mechanical protection requirements
• Perform steady state hydraulic analysis and determine pump or compressor station requirements and spacing
• Assess surge and transient behaviour and specify appropriate protection measures
• Plan and execute pigging operations for cleaning, batching, dewatering and inspection
• Specify corrosion control including coatings, cathodic protection, inhibition and internal corrosion management
• Select in-line inspection tools, interpret their output and assess reported defects against recognised assessment methods
• Apply pipeline integrity management principles including threat assessment, risk ranking and reassessment intervals

The training follows the pipeline lifecycle from design through construction, commissioning and operation to integrity management and decommissioning, so that each topic is placed in the context of the decisions that preceded it. Wall thickness, hydraulic profile, surge estimation, cathodic protection current demand and defect assessment calculations are worked through numerically. In-line inspection reports, cathodic protection survey data and integrity assessment outputs are examined and interpreted. Failure case histories from onshore and offshore pipelines are analysed for the control that was absent or ineffective, and participants are encouraged to bring pipeline integrity or operating questions from their own systems.

Organisations sending participants to this training will:

• Reduce pipeline failure risk through better application of corrosion control and integrity management practice
• Improve the technical quality of in-line inspection programmes and the decisions taken from their results
• Reduce unnecessary repair and replacement spend through sound defect assessment rather than conservative default action
• Improve pipeline throughput and energy efficiency through better hydraulic and operating optimisation
• Strengthen regulatory compliance and integrity assurance documentation
• Improve emergency preparedness and response capability for pipeline incidents

Participants will:

• Understand pipeline design decisions and the codes and assumptions behind them
• Interpret in-line inspection and cathodic protection survey data with technical confidence
• Assess reported defects and judge whether a pipeline can continue to operate safely
• Plan pigging and pipeline operations competently, including their hazards
• Contribute to integrity management planning and threat assessment
• Build capability applicable across upstream, midstream and transmission pipeline operations

• Pipeline engineers and pipeline operations personnel
• Facilities, process and production engineers with pipeline responsibility
• Integrity, corrosion and inspection engineers
• Maintenance and technical support staff for pipeline systems
• Project and construction engineers working on pipeline projects
• Control room operators and supervisors responsible for pipeline systems
• HSE and regulatory compliance staff supporting pipeline assets

Upon successful completion of this training course, delegates will be awarded an official Certificate of Completion issued by the Petroleum Engineers Association (PEA), an ISO 9001:2015 certified training organization. The certificate carries 10 Credits and formally records the total learning hours completed.

Each certificate is signed by the Course Facilitator and the CEO of the Petroleum Engineers Association, and serves as verifiable proof of professional training that delegates can present to employers and professional bodies worldwide.