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SPE 124539 Application of Risk Based Inspection to Offshore Facilities

Tony Poulassichidis, Hess Corporation

Copyright 2009, Society of Petroleum Engineers This paper was prepared for presentation at the 2009 SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, USA, 4­7 October 2009. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright.

Abstract The Risk Based Inspection (RBI) process delivers a calculated risk value for each fixed equipment item in a facility. Fixed equipment risk values are the product of the Likelihood-of-Failure (LOF) and the Consequence-of-Failure (COF) factors. The calculated equipment risk values are used to optimize the facility inspection program in accordance with industry best practices (API-580/2002, API-581/2008). This paper will present the results from a RBI analysis of Gulf of Mexico (GOM) topsides facilities. Requirements for successfully implementing and maintaining a RBI program will be reviewed. Using the RBI calculated risk values, a fixed equipment relative risk ranking is established that strengthens the facility mechanical integrity program by allowing the operator to: ­set priorities and focus their attention on the critical areas ­justify capital investment for lifetime extension projects ­proactively address loss of primary containment and process safety issues In addition to improved mechanical integrity, using RBI as a basis for inspection planning can aid in a cost/benefit optimization analysis of inspection work year over year. Recent regulation updates require compliance with the API-510 inspection code for production operations in the "outer continental shelf" (30 CFR 250.803.b). API-510 code translates to a time-based inspection interval requirement after a maximum of 10 or 15 years in-service depending on pressure vessel classification. As an alternative to the time-based inspection requirements, the API-510 inspection code allows the use of RBI analysis. In the case of this particular GOM platform, the RBI analysis resulted in an 80% reduction of the above-mentioned timebased inspection requirements while at the same time ensuring equipment mechanical integrity needs are met. In conclusion, RBI technology is · an intelligent database system · compliant with industry best practices for fixed equipment risk management · decision enabler for asset management based on a quantitative data analysis allowing the operator to do the "right thing", focusing on cost effectively reducing operational risk Keywords: Risk-based inspection, RBI, mechanical integrity, offshore topsides

Regulations Fixed equipment inspection requirements for production platforms are defined in section 250.803 of federal regulations Title 30 (Title-30/2009). This federal regulation was revised in March 2005, and now incorporates the requirements for compliance with API-510 Vessel Inspection Code (Federal register/2005).


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