Pipeline Integrity Management

Transcription

1 Pipeline Integrity Management Alberta-Korea Pipeline Safety Seminar Daegu, South Korea June 2, 2016 Brian Wagg Director, Business Development C-FER Technologies Edmonton, Alberta, Canada

2 Overview Introduction to C-FER Integrity Management Programs Program Requirements Initial Assessments Making the most of ILI data

3 Who we are Independent engineering consulting and testing Not-for-profit, Government owned 100 employees - $18 million annual revenue Working with industry clients

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5 What we do Improve Safety and Efficiency Modeling Manage Risk Optimize Operations Investigate Failures Testing De-risk technologies Qualify Equipment Track Performance Risk

6 Integrity Management Plan Construction Avoid Integrity Management Prevent Leak Detection Find Spill Response Clean up

7 IMP Requirements System Data Records Management Change Management Training and Competency Hazard Identification Consequence Identification Inspection and Monitoring Mitigation Options Activity Plans and Schedules Continual Improvement Incident Investigation

8 IMP Assessment

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10 IMP Assessment Pipeline Operator 3 rd Party Inspector IMP Assessment Regulator

11 IMP Requirements System Data Records Management Change Management Training and Competency Hazard Identification Consequence Identification Inspection and Monitoring Mitigation Options Activity Plans and Schedules Continual Improvement Incident Investigation

12 Hazards Equipment impact External metal loss corrosion Internal metal loss corrosion Stress corrosion cracking Manufacturing defects Geotechnical hazards Seismic hazards Ice scour (offshore) Natural hazards (offshore)

13 Baseline Assessments Objective Identify pipeline segments where risk or uncertainty is highest Approach Requires minimal data to describe pipeline attributes Use database of pipeline failures to estimate probability of failure for each hazard

14 Data Requirements Pipeline attributes for external corrosion analysis: Age Wall thickness Operating temperature Soil corrosivity (low / high / very high) Cathodic protection (yes / no) Coating type Coating condition (intact / damaged)

15 Segment Analysis

16 Detailed Assessments Objective Develop work plans to reduce risk Approach Collect data to better describe pipeline condition (e.g. Inline inspection, digs, etc.) Use engineering models to estimate risk Optimize plans to reduce risk

17 Defect Assessment Process Maximum operating pressure Measurement uncertainties Data on pipe properties and dimensions Inspection Data Corrosion model and test results Data from repetitive inspections pipe properties Frequency Yield stress (MPa) corrosion characteristics Prob. density Flaw depth (mm) model uncertainties Test results x x x x x x x x x x x Model results corrosion growth rates Prob. density Growth Rate (mm/yr) Failure probability as a function of time

18 Probability of Detection

19 Initial Assessment - Basic line attributes - Failure database used to estimate probability of failure due to each hazard

20 Detailed Assessment - Inline Inspection shows pipe wall loss due to corrosion - Engineering models used to predict probability of failure due to corrosion - Other hazards use failure database

21 - Risk = Probability of Failure x Consequences - Risk target consistent along pipeline Consider Consequences

22 Repair Damage

23 Install Protection

24 Maintenance Planning Base case Failure Rate (per km yr) Reduced pressure In-line inspection Increased wall Relative Age (yrs)

25 Dig Optimization Year 1 Year 4 Year 5 Year 8

26 PIRAMID Quantify risk profile along pipeline Evaluate factors influencing risk Optimize maintenance and inspection programs Report to regulators

27 Integrity Management Program Well established best practices are documented in standards Baseline risk assessments require only basic information and use a database of failures from other pipelines More detailed assessments can be made when more data becomes available Maintenance programs can be optimized to minimize risk and cost

28 Thank you