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Risk-Based Pipeline Integrity Management
Knowledge Transfer›Pipeline Engineering & Integrity
Pipeline Engineering & Integrity·Certification Pathway

Risk-Based Pipeline Integrity Management

Pipeline integrity management engineering principles covering threat identification, risk assessment, ILI, ECDA, ICDA, corrosion modelling, integrity assessments, mitigation, and repair — aligned with CSA Z662, ASME B31.8S, and API 1160.

Duration3 days
DeliveryOnline / Virtual
LocationTES Canada facility · Client facility delivery available
LevelSpecialist
Certifying BodyTES Canada
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Course Overview

This course provides a comprehensive engineering foundation in pipeline integrity management systems (PIMS), applied to onshore liquid and gas transmission pipelines. It covers the full PIMS framework — threat identification, risk assessment, ILI tool selection, external and internal corrosion direct assessment (ECDA and ICDA), corrosion modelling, integrity assessment, and mitigation — aligned with CSA Z662, ASME B31.8S, API 1160, and DNV RP-F116. Case studies illustrate real-world application of integrity management decision-making. The course is designed for pipeline integrity engineers, operations engineers, and technical personnel responsible for pipeline integrity programs.

Who Should Attend

Pipeline integrity engineers developing or managing pipeline integrity management programs
Operations and maintenance engineers responsible for pipeline system integrity
Regulatory affairs and asset management personnel requiring technical PIMS understanding
Project engineers involved in pipeline inspection programs and integrity decisions
Prerequisites

Engineering degree or technical qualification with some background in pipeline operations, inspection, or engineering. The Onshore Pipeline Engineering course or equivalent knowledge is recommended.

Learning Outcomes

  • Explain the pipeline integrity management framework under CSA Z662, ASME B31.8S, and API 1160
  • Identify and classify pipeline threats using the standard threat taxonomy
  • Apply qualitative and semi-quantitative risk assessment methods for pipeline integrity
  • Select and plan ILI programs for pipeline threat assessment
  • Apply ECDA and ICDA direct assessment frameworks
  • Apply corrosion rate modelling and integrity assessment for corrosion threats
  • Evaluate pipeline anomalies and make integrity decisions using assessment standards
  • Select and evaluate pipeline repair and mitigation options

Course Outline

Module 01

PIMS Framework and Codes

Pipeline integrity management system (PIMS) definition and scope
CSA Z662 Annex N — Canadian pipeline integrity management requirements
ASME B31.8S — gas transmission integrity management overview
API 1160 — liquid pipeline integrity management
DNV RP-F116 — integrity management for submarine pipelines
High-consequence area identification and regulatory requirements
Module 02

Threat Identification and Classification

Pipeline threat taxonomy — time-dependent, time-independent, stable
Time-dependent threats — corrosion (internal, external, SCC), cracking
Time-independent threats — third-party damage, incorrect operations
Stable threats — construction defects, manufacturing defects
Threat screening and prioritisation methodology
Module 03

Risk Assessment for Pipeline Integrity

Qualitative risk assessment — scoring and matrix methods
Semi-quantitative risk assessment — index models
Consequence modelling overview — gas, liquid, multiphase releases
Likelihood of failure assessment for corrosion and mechanical damage
Risk ranking, prioritisation, and risk tolerance criteria
Module 04

In-Line Inspection

ILI tool types — metal loss (MFL, UT), geometry, crack detection (EMAT, UT)
Tool selection for threat type and pipeline conditions
ILI sizing accuracy — tolerances and confidence levels
ILI data analysis — anomaly identification and classification
Field verification and excavation sampling
Module 05

External Corrosion Direct Assessment (ECDA)

ECDA framework — NACE SP0502
Pre-assessment — data collection and indirect inspection tool selection
Indirect inspection methods — CIPS, DCVG, PCM, and aboveground survey
Direct examination — excavation criteria, corrosion assessment, CP evaluation
Post-assessment — remaining life and re-assessment interval
Module 06

Internal Corrosion Direct Assessment (ICDA)

Dry gas ICDA — NACE SP0206 framework
Wet gas ICDA for condensate-forming systems
Liquid petroleum ICDA for crude oil and product pipelines
Critical inclination angle and flow modelling for water accumulation
Corrosion monitoring integration with ICDA results
Module 07

Corrosion Modelling and Monitoring

Internal corrosion rate models — empirical and mechanistic
Chemical injection and corrosion inhibition program evaluation
Corrosion monitoring methods — coupons, ER probes, FSM
Corrosion data management, trending, and reporting
Integrating monitoring data with integrity assessment
Module 08

Integrity Assessment and Decision-Making

Selecting assessment method for identified anomaly type
Metal loss assessment — ASME B31G, DNV RP-F101
Crack assessment — BS 7910 and SCC growth modelling
Remaining life determination and reassessment interval
Fitness-for-service decision framework — accept, monitor, repair, decommission
Module 09

Mitigation, Repair, and Case Studies

Preventive mitigation — coatings, CP enhancement, inhibitor programs
Repair methods — sleeves, hot taps, clamps, and pipe replacement
Pressure restrictions and pressure testing as interim measures
Emergency response and incident management
Case study — ILI program development and anomaly disposition
Case study — ECDA implementation example

Topics Covered

Pipeline Integrity ManagementPIMSCSA Z662ASME B31.8SAPI 1160ILIECDAICDACorrosion ManagementRisk Assessment
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