1 / 46

APPROACHES TO INTEGRITY MANAGEMENT OF PIPELINES PROMOTED IN TECHNOLOGICAL ADVANCE COUNTRIES

APPROACHES TO INTEGRITY MANAGEMENT OF PIPELINES PROMOTED IN TECHNOLOGICAL ADVANCE COUNTRIES. M. Borysiewicz , S. Potempski Instytut Energii Atomowej, Centrum Doskonałości MANHAZ. R egulations. UK

robbin
Télécharger la présentation

APPROACHES TO INTEGRITY MANAGEMENT OF PIPELINES PROMOTED IN TECHNOLOGICAL ADVANCE COUNTRIES

An Image/Link below is provided (as is) to download presentation Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author. Content is provided to you AS IS for your information and personal use only. Download presentation by click this link. While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server. During download, if you can't get a presentation, the file might be deleted by the publisher.

E N D

Presentation Transcript


  1. APPROACHES TO INTEGRITY MANAGEMENT OF PIPELINES PROMOTED IN TECHNOLOGICAL ADVANCE COUNTRIES M. Borysiewicz, S. Potempski Instytut Energii Atomowej, Centrum Doskonałości MANHAZ

  2. Regulations UK Regulation 23 requires the operator of a major accident hazard pipeline to have available a 'Major Accident Prevention Document' (MAPD). The MAPD is a management tool to ensure that the operator has assessed the risk from major accidents and has introduced an appropriate safety management systemto control these risks. A 'major accident' is defined as 'death or serious injury involving a dangerous fluid'.

  3. Requirements of a MAPD

  4. Regulations • Canada • Risk assessment and management is being promoted by the Pipeline Risk Assessment Steering Committee, which has developed a Canada-wide database of reportable pipeline incidents and characteristics. • Appendix 'Guidelines for Risk Analysis of Pipelines' was included in the Canadian Standards Association Standard Z662 in 1996.

  5. Regulations • USA • In 1998, the USA Office of Pipeline Safety signed a 'risk management demonstration project order' approving Shell as the first participant in their risk management demonstration program. • DoT 49 CFR 195.452 Pipeline Safety Regulation: Pipeline Integrity Management in High Consequence Areas; • API nr 1160 - US Standard:Integrity Management System of Pipelines Conveying Dangerous Fluids.

  6. Risk Management - the approach adopted in the USA The approach is the USA is to implement a complete risk management program on a pipeline system, which includes a riskassessment, control, performance monitoring and feedback. It also requires operators to ensure that risk management is integrated with the company's business practices.

  7. Risk Management - the approach adopted in the USA

  8. Risk management has been defined by the USA Office of Pipeline Safety as: 'a comprehensive management decision support process, implemented as a program, integrated through defined roles and responsibilities into the day-to-day operations, maintenance, engineering management, and regulatorydecisions of the operator'

  9. Risk Management is a continuous process. Risk cannot be completely eliminated. Risk can be controlled through the cost-effective application of finite resources. Risk Management increases, integrates, and enhances the value of informationconcerning pipeline safety. Risk Management programs are structured but flexible, allowing customized approachesto be developed for specific issues and situations, encouraging innovation, and supportingcontinuous improvement. Risk management program (1)

  10. The implementation of a risk management program should result in superior public safetyand environmental protection. Risk Assessments are critically dependent on the information requested and gatheredfrom field operations through an open dialogue format. Inclusion of operational and technical personnel into the System Integrity Programensures accuracy and validates the results of the relative risk ranking results. Risk management program (2)

  11. Management Systems Pipeline operators and regulators are recognising the importance and usefulness of formal 'management systems'. A Pipeline Management System is expected to be a requirement inall countries of the European Community in thenear future. Risk Management Programmes in a Company's Management System

  12. Proactive activities for identification, analysis and management of risk associated with the operation and assets of pipeline – implementation of coherent Safety Management Systemand its key-element - Pipeline System Integrity Plan (PSIP); Requirements for pipeline operator (1)

  13. operation and maintenance of pipeline assetsin a manner that ensures the long-term safety; implementation of proactive practice of the prevention of accidentsthrough Pipeline System Integrity Plan (PSIP); collaboration with all stakeholders, which includes the public and regulatory agencies, to optimize the opportunity for success of PSIP. Requirements for pipeline operator (2)

  14. Pipeline System Integrity Plan -(PSIP) (1) Pipeline System Integrity Plan is specifically designed to identify, assess, and manage those elements and attributes that could lead to the inadvertent release of hydrocarbon products to the environment.

  15. The primary areas of PSIP include the following: An initial and ongoing assessment of the mechanical condition of the pipelinecomponents; An initial and ongoing assessment of controlling devices to ensure that operatingpressures remain within safe parameters; Internal analysis of product characteristics and protection efforts to eliminateissues of internal corrosion; Mitigation plans to eliminate issues of external corrosion; Third party damage prevention programs; Analysis of potential impacts to pipeline integrity resulting from actsof nature,such as earth movement, water caused erosion, and flooding. Pipeline System Integrity Plan -(PSIP) (2)

  16. Pipeline System Integrity Plan -(PSIP) (3) • PSIP has two fundamental components: • The first component includes a focus on themitigation of Third Party Damages, Corrosion, Incorrect Operations, and MechanicalDesign/Installation. • The second component is a detailed segmenting of the pipeline with respectto population density, drinking water supplies, endangered species and recreation areas.

  17. Pipeline System Integrity Plan -(PSIP) (4) The two components, likelihood andconsequence, allow for the targeted analysis of those potential occurrences that could have thegreatest impact on the environment or the public in the event of a product release. With aheightened awareness of targeted physical areas, a "Scenario Based Analysis" will be performedto identify, assess, and manage associated risks.

  18. Corrosion Management Plan; In-Line Inspection and Rehabilitation Program; Key Risk Areas Identification and Assessment; Damage Prevention Program; Encroachment Procedures; Incident Investigation Program; Pipeline System Integrity Process - Elements: (1)

  19. Management of Change; Depth of Cover Program; Fatigue Analysis and Monitoring Program; Scenario Based Risk Mitigation Analysis; Incorrect Operations Mitigation; System Integrity Plan Scorecarding and Performance Metrics Plan. Pipeline System Integrity Process -Elements: (2)

  20. Overall system integrity and risk management process. Capital and maintenance funding oversight. Incorporation of the management of change process. Development and distribution of system integrity status reporting centralization of pipeline attribute data. Assessment and analysis of identified areas of risk. Oversight and execution of the risk assessment model and development andmaintenance of the relative risk assessment of the pipeline system. Pipeline System Integrity – Problem Groups: (1)

  21. Oversight of risk mitigation initiatives. Capital and maintenance funding oversight and allocation of risk mitigationinitiatives not related to routine operation and maintenance requirements. Continuously evaluating new technology, new risk assessment processes, newmitigation processes and similar activities in a concerted effort to improve overallsystem integrity process. Pipeline System Integrity – Problem Groups: (2)

  22. Depth of cover surveys. Population density surveys. Land use and activity surveys. One-Call activity levels surrounding the pipeline right-of-way easements. Aerial patrol records, encroachment sightings, corrosion monitoring andmaintenance program. Programs which contribute to the PSIP risk assessment model include: (1)

  23. Internal corrosion coupon monitoring program. Right-of-way condition monitoring and maintenance leak history reports. Root cause analysis and incident investigations. Cleaning pig reports and debris analysis. Excavation reports and third party crossing line inspections. Programs which contribute to the PSIP risk assessment model include: (2)

  24. Pipeline coating condition reports. Metallurgical analysis of coupons. Smart pig results analysis. Third party pipeline crossing inspections and cathodic protection interference data. Programs which contribute to the PSIP risk assessment model include: (3)

  25. GIS mapping information and participation with the OPS National PipelineMapping System (NPMS) Program. Metallurgical analysis of corrosion coupons and pipe cut outs. Metal fatigue analysis and pressure cycling operational data. Operational Reliability Assessment. Programs which contribute to the PSIP risk assessment model include: (4)

  26. Operational Reliability Assessment - (ORA)(1) The ORA adjusts integrity verification frequencies in response to changing uncertainties over time, in response to environmental changes along the pipeline route and in response to data collected from integrity testing, additional attributes, changed attributes, root cause analysis results, or other programs identified in the PSIP. The ORA is conducted on an annual basis.

  27. Operational Reliability Assessment- (ORA)(2) The ORA specifically includes the results and data attributes of all internal inspection logs, close interval surveys, line condition reports, terminal and pump station inspection reports, product corrosivity reports, fatigue monitoring, and all other relevant system attributes, or other changes which would impact failure probability.

  28. Operational Reliability Assessment- (ORA)(3) The ORA is specifically intended to incorporate the results of all elements of the PSIP as attributes and data to consider in the overall assessment of the mechanical condition of the pipeline system assets. The PSIP or other initiated internal or external third party studies and evaluations, such as earth movement studies that may include specific areas such as landslide, erosion, scour and subsidence, will be made available to and incorporated into the ORA evaluation.

  29. Scenario Based Risk Mitigation Analysis(1) • Scenario based risk mitigation assessments typically focused on items including: • pipeline operations, • maintenance, • physical pipeline components, • pipeline patrol, • ccorrosion inspection, • depth of cover, and • public education.

  30. Scenario Based Risk Mitigation Analysis(2) The intent is to analyze those aspects of pipeline operations and maintenance that could lead to the release of product into the environment. Primary focus in a scenario based assessment is on mechanical integrity, operating controls, and the prevention of third party damage.

  31. Incident Data: number and volume of releases. Risk Awareness: identification of new and/or previously unrecognized risks (new projects). Public Customer Service: number of validated complaints on safety or environmental issues; number of landowner contacts related to pipeline safety and land use. Operator Resources and Innovation: number of new technologies, alternative methodologies and innovative approaches to control risk. Performance Measurementof PSIP – general criteria(1)

  32. Corrosion Management Plan: smart pig results. Depth of Cover Program: number, type, and location of third party damage incidents. Damage Prevention Program: number of third party damage incidents due to One-call Process not being practiced. Performance Measurementof PSIP – specific criteria(2)

  33. A synopsis of the most important integrity issues being addressed on thepipeline system and the status of activities and programs used tomanage these risks. Important insights, results, and lessons learned from the previous years. Pipeline System Integrity Plan Audit(1)

  34. Insights from new integrity management processes or technologies, or innovativeapplications of existing technologies. Performance measurement results. New integrity management programs or activities that will be conducted, orsignificant improvements to existing programs and activities. Pipeline System Integrity Plan Audit(2)

  35. Computer programs supporting PSIP • GE Oil & Gas: PII Pipeline Integrity Evaluation (PIE)(1) • collection and integration of all available data concerning pipeline integrity, gathered from multiple sources and installed in a central Integrity Management database. Data include results of following • in-line inspections: • Metal Loss Detection • Three tool ranges are recommended for pipelines in which internal or external corrosion is an issue. They will also detect mechanical defects such as gouges, dents and faulty welds. • MagneScan – locates general corrosion in gas and liquid lines • UltraScan WM– locates and measures corrosion in liquid lines • TranScan – locates axial defects and grooves in both gas and liquid lines

  36. Computer programs supporting PSIP GE Oil & Gas: PII Pipeline Integrity Evaluation (PIE)(2) 2. Crack Detection Four tools are recommended for the detection of critical and subcritical cracking and similar narrow axial defects: UltraScan CD– locates and measures fine cracks in liquid lines EmatScan – locates and measures fine cracks in gas lines TranScan – locates flaws in the seam weld and axial defects Elastic Wave– locates and measures cracks in gas lines

  37. Computer programs supporting PSIPGE Oil & Gas: PII Pipeline Integrity Evaluation (PIE)(3)

  38. GE Oil & Gas: PII Pipeline Integrity Evaluation (PIE)(4) LIQUID INTEGRITY ELEMENTS FRAMEWORK OUTLINE

  39. Bass-Trigon:Pipeline Compliance System (PCS)(1) Bass-Trigon's PCS software solution is the product of a team of experienced Corrosion Engineers and software development professionals. With over 1,500 installed sites at more than 150 companies throughout the world, the PCS database and application software are proven leaders in the pipeline corrosion and maintenance industry. Computer programs supporting PSIP

  40. Bass-Trigon:Pipeline Compliance System (PCS)(2) The PCS database is fully ODBC compliant allowing for integration with other databases such as GIS, ERP, Asset Management and Enterprise systems. Computer programs supporting PSIP

  41. Bass-Trigon’s Pipeline Compliance System includes the following features: Modular design to meet the needs of Transmission and Distribution companies. Efficiently stores very large data sets for use by all modules. Extensive graphing and troubleshooting capabilities. Flexible user interface. Designed by pipeline experts for the pipeline professional. Supports compliance with valid regulations and standards. Results in shorter audit times. Easily manage data among field computers, laptops, desktops and servers. ODBC compliant database for integration. Computer programs supporting PSIP

  42. Computer programs supporting PSIP BASS TRIGON: Integrity Assessment Program (IAP)(1) IAP is the industry leading integrity and risk assessment application for natural gas andhazardous liquids pipeline systems. Using an accepted relative risk assessment methodology, IAP locates areas of high risks, prioritizes pipeline segments based onseven failure and three consequence risks, and supports effective resource allocationdecisions through detailed integrity assessment and project scenario analysis.

  43. BASS TRIGON: Integrity Assessment Program (IAP)(2) Technical Highlights (1) risk algorithm assesses impact of more than 200 variablesand is user configurable based on operator experience andengineering judgement; flexible data entry grids and import routines provide for efficient pipeline modeling; risk calculations may be performed for varying pipelinesection lengths or as critical variables change; extensive risk analysis pin-points high risk areas,determines root cause risk drivers and prioritizes pipelinesegments and sections for risk optimization; calculates pressure test versus elevation values, MAOP,ANSI B31G, %NOP vs 100% SMYS, rupture volumesand other critical pipeline calculations; Computer programs supporting PSIP

  44. BASS TRIGON: Integrity Assessment Program (IAP)(3) Technical Highlights (2) powerful ad-hoc graphic’s engine displays integrity datain multi-varient, two-dimensional profiles; project scenario and benefit\cost analysis functionalityfacilitates project selection; database capable of managing more than 500 fields; connectable to ISAT and PODS database designs; compatible with Bass-Trigon Cathodic Protection Data; Management Program (CPDM) and Pipeline ComplianceSystem (PCS). Computer programs supporting PSIP

  45. Integrated Data Management DATA FLOW THROUGH THE INTEGRITY CYCLE

More Related