Spoolable non-metallic pipe (NMP) is recently getting increased popularity as material for onshore and offshore pipeline. Even though the material is generally more expensive than conventional carbon steel, the total life cycle cost (TLCC) reduction is driven by reduction of pipeline installation cost (faster lay rate, less manpower/equipment) and operational cost (no chemical injection to combat corrosion, less operational pigging and inspection). The most common types of spoolable NMP currently used are reinforced thermoplastic pipe (RTP) and thermoplastic composite pipe (TCP). Non-metallic composite material strength capacity to withstand internal pressure is naturally decreasing over time. As new material, limited long-term performance data are currently available for these types of pipes. To obtain the long-term strength degradation properties of the material requires long duration and expensive qualification process, which burden the development of these types of pipes. PETRONAS has performed series of qualification test for both RTP and TCP in collaboration with several manufacturers. The qualification was initially based on API RP 15S (edition 2006) with few additional testing to suit offshore application due to the recommended practice initially only covers spoolable RTP and generally for onshore application. The latest edition as specification (API Spec 15S) covers more general types of spoolable plastic line pipes, including bonded (fully non-metallic reinforced plastic pipe) and unbonded type (with metallic reinforcement). Recently DNV also issued DNV RP F119 in 2015, a recommended practice for TCP, which subsequently upgraded to become specification, DNVGL ST F119 in 2018. Both reference specifications/standards above have different requirements on how to design and qualify the reinforced plastic pipe, however in general, both are based on long term test requirement. This paper provides requirement of long-term qualification of the pipe, based on API RP/Spec 15S and compare the result if it is qualified in accordance to DNVGL ST F119. Different result in term of long-term strength capacity is observed between these two standards. This paper also explains the pros and cons and provide feedback to both referenced specifications above, to further improve the specification requirements and reduce the burden of either manufacturer or end user in performing qualification for the pipe.
Pipeline Leak Detection System (PLDS) is a hardware and/or software-based monitoring tools that is utilized to indicate a leak or hydrocarbon release along the pipeline. However, it is noted that most pipelines are not equipped with PLDS as risks associated with the pipeline are mitigated by other means or deemed low. Another issue is that the current leak detection technology is not a full proof system i.e. it may still be giving false leak alarms or inaccuracies in the leak location. PETRONAS Procedures and Guidelines for Upstream Activities (PPGUA) calls for installation of Subsea Safety Isolation Valve (SSIV) for protection and risk mitigation measures to the new pipeline installed, particularly for gas pipelines or where pipelines are connected into major trunk pipeline systems with large connected inventories. A justification shall be provided if SSIV are not installed. A risk assessment study and cost benefit analysis should be performed to justify the use of PLDS and installation of SSIV. High risk pipelines such as those transporting volatile, corrosive, flammable or toxic fluids in significant volume in high consequence areas may benefit from the use of PLDS and SSIV in limiting the inventory leaked to the environment and the resulting consequence. PETRONAS Technical Standard (PTS) specifies that the requirement for PLDS and SSIV for new pipelines is to be determined via a semi-quantitative Risk Assessment or a fully Quantitative Risk Assessment (QRA).
Managing pipeline integrity revolves around abundance of data and information from monitoring of safe operating limits, inspections and maintenance. Those data and information may come from real-time/on-line systems, manually input ad-hoc, manually input from inspections and maintenance carried out on a particular pipeline. The oil and gas pipeline industry have sort of mature with respect to having a software/tool in aiding and assisting personnel in performing risk, fitness-for-service, repair assessments, and executing management of change for a pipeline system; and many more assessments/analyses. Nevertheless with the invent of analytics, there is strong need to explore the new ways of working with those abundance data and information OR maximising the utilisation of the data and information for the benefit of assessing or evaluating pipeline's risk and integrity to predict 'accurately' risk and integrity so that specific and cost-effective actions and mitigations can be deployed within a stipulated period of time. In those regard, PETRONAS is actively working with industry to establish predictive analytics for critical offshore and onshore pipelines' threats/anomalies i.e. internal corrosion and free span for offshore; and external corrosion and geotechnical hazard for onshore. This paper will dwell on the principles, concepts and methodology of predictive analytics tools for the development. It is envisaged that eventually those threats/anomalies will be analytics-managed to eliminate unwanted incidents to PETRONAS's offshore and onshore pipelines. In addition, analytics-pipeline integrity management will also likely to provide 'accurate' prediction of 'future' pipeline integrity.
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