International Journal of Pressure Vessels and Piping
Comparison of API 510 pressure vessels inspection planning with API 581 risk-based inspection planning approaches
Introduction
Based on jurisdictional requirements all pressure containing equipment must be inspected according to appropriate inspection code to ensure its mechanical integrity for continuing service [1], [2]. The main reason of inspection is the activity of damage mechanisms which leads to loss of mechanical integrity of equipment over the time. One of the most important issues in pressure vessel inspection is “when to inspect pressure vessels”.
Setting the intervals/due dates between inspections has evolved over time. With the need to periodically verify equipment integrity, organizations initially resorted to time-based or “calendar-based” intervals/due dates. With advances in inspection approaches, and better understanding of the type and rate of deterioration, inspection intervals/due dates became more dependent on the equipment condition (i.e. condition-based inspection), rather than what might have been an arbitrary calendar date. Codes and standards such as API 510 (Pressure Vessel Inspection Code), API 570 (Inspection, Repair, Alteration, and Rerating of In-service Piping Systems), and API 653 (Tank Inspection, Repair, Alteration, and Reconstruction) evolved to an inspection philosophy with elements such as inspection intervals/due dates based on some percentage of equipment life (such as half-life), on-stream inspection in lieu of internal inspection based on low deterioration rates, internal inspection requirements for damage mechanisms related to process environment induced cracking and consequence based inspection intervals/due dates.
RBI represents the next generation of inspection approaches and interval/due date setting, recognizing that the ultimate goal of inspection is the safety and reliability of operating facilities. RBI, as a risk-based approach, focuses attention specifically on the equipment and associated damage mechanisms representing the most risk to the facility. In focusing on risks and their mitigation, RBI provides a better linkage between the mechanisms that lead to equipment failure (loss of containment) and the inspection approaches that will effectively reduce the associated risks [3].
In this study, the results of implementation of RBI technology in two distillation units are presented. In addition, the inspection intervals are calculated based on API 510 inspection code. Then the results are compared to each other. Both distillation units convert crude oil to lighter products such as kerosene, naphtha, diesel, etc. in atmospheric and vacuum distillation towers with a capacity of about 150,000 BPD. The general information about the distillation units under study is shown in Table 1.
Section snippets
Risk analysis methodology
Basically there are three approaches to risk assessment: (1) qualitative, (2) quantitative, and (3) semi-quantitative. Qualitative risk analysis is an analysis that uses broad categorizations for probabilities and consequences of failure, while quantitative risk analysis uses logic models depicting combinations of events that could result in severe accidents and physical models depicting the progression of accidents and the transport of a hazardous material to the environment. Semi-quantitative
Risk analysis results
Risk analysis based on API RBI methodology was conducted on the pressure components of two distillation units (see Table 1). The results of area-based risk analysis are shown as risk distribution charts in Fig. 4a and b. The numbers shown on matrices are the number of equipment which their risk corresponds to that area of risk matrix. The distribution charts show that the most of equipment pieces are located in low and medium risk areas. Just 12% of EORC equipment and 15% of AORC equipment are
Conclusions
Risk-based inspection technology was successfully implemented in crude distillation units of Abadan Oil Refinery and Esfahan Oil Refinery. Only a small percentage of equipment items, 12% and 15% respectively for EORC and AORC plants, were categorized as high risk or high–medium risk.
The calculated inspection intervals reveal that in both units there exists some equipment with inspection intervals less than current overhaul (turnaround) intervals, and also lots of items with inspection interval
Acknowledgments
This paper presented the results from two research projects supported by the Abadan Oil Refining Company (AORC) and Esfahan Oil Refining Company (EORC). A word of thanks goes to all personnel of AORC and EORC due to their full support during implementation of studies.
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