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McLeod, Ronald W. (Ron McLeod Ltd.) | Novia, Mathew (Baker Hughes, a GE company) | Nonno, Lamberto (Baker Hughes, a GE company) | Acton, Sarah (Baker Hughes, a GE company) | Easton, Neil (Baker Hughes, a GE company)
Abstract In common with every company involved in the global upstream oil and gas industry, oilfield service companies rely to a large extent on front-line operators monitoring key operational parameters in real time, and being willing and able to intervene in the event where signs of potential trouble are detected. Many factors—personal, inter-personal, organizational, and technological—have the potential to interfere with the ability of individuals to perform monitoring tasks to the required standard. This paper presents the results of a study carried out to evaluate the quality of implementation of arrangements supporting proactive operator monitoring. The study comprised two components elements: i) a review of incidents where operator monitoring played some role, and ii) semi-structured interviews of operator representatives including subjective ratings of monitoring quality. The situating questions allowed operator representatives a chance to reflect on the nature of the monitoring tasks, and their experience of potential disrupting factors, before attending the workshop. A bespoke tool—the Proactive Operator Monitoring Assessment Tool (POMAT)—was developed, enabling assessors to rate the quality of implementation of operator monitoring tasks. The tool is based on ratings on four dimensions (ownership, signals, context, and resilience) comprising a total of eight criteria. Based on the subjective ratings, a Proactive Monitoring Quality (PMQ) score was calculated that indicates how robust the implementation of each operator monitoring task that is relied on as a barrier is thought to be. This paper describes the method used in the study, and explains the use of the POMAT tool and how PMQ scores are calculated. The application of the method to assess operator monitoring during coiled tubing and tubular cutting and milling operations are used as examples. The POMAT tool and PMQ score represent novel approaches for evaluating the likely strength of proactive operator monitoring barriers where they exist in corporate bowties to determine if they can in fact be relied upon as an effective, independent, auditable barrier.
Copyright 2011, Society of Petroleum Engineers This paper was prepared for presentation at the SPE/ICoTA Coiled Tubing and Well Intervention Conference and Exhibition held in The Woodlands, Texas, USA, 5-6 April 2011. 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 This paper describes a Direct Fired Liquid Nitrogen Vaporizer Automation System (LN2 Vaporizer Automation) and the control equipment and techniques associated therein. This system has been developed over the last two years and has proven capable of controlling the discharge temperature of discharged nitrogen gas, across a broad range of rates and pressures in a wide range of ambient conditions, while controlling pollutants from the burner and providing for enhanced safety and reliability. The key components of the system are: a.
The number of fields being developed navigation mode. Co., originally presented at the 2001 Introduction A new BHA and LEGS are sufficiently Depth Correlation small to pass through completion tubing Because of uncertainty about the degradation of seals and metal components and function in typical casing and liner length of CT in the hole, positioning and reduces maintenance and diameters. The new BHA is an intelligent the BHA across the lateral entrance redress costs. Water is the most commonly robotic device and controls its actions as can be difficult. To find the lateral used liquid.
Coats, Catherine G. (Halliburton Energy Services, Inc.) | LeBoeuf, Gerald (Halliburton Energy Services, Inc.) | Dupont, Richard (Halliburton Energy Services, Inc.) | Wilson, Bradley (Apache Corporation)
Proposal A major operator in the Gulf of Mexico had planned to run a cased, slimhole completion. The formation was sandstone, and thus, gravel packing would be required. The well was drilled, but the liner became stuck at 1500 feet from bottom. The operator did not want to pursue the sidetrack option, and unless another solution could be developed, the well project would have to be abandoned. The service/engineering company working with the operator felt that a solution could be developed that would allow the well to be completed. The operator and service company representatives formed a dedicated team and developed a plan that would provide the perforation needs, solve the packer problem, and perform the gravel pack satisfactorily from a service vessel. This paper will discuss how an unusual solution was planned and executed and was successful in resolving the problems. This case history is an example of how a service company and operator can work together to resolve difficult completion scenarios and provide win/win solutions for all parties. With regards to innovative completion techniques, the completion configuration that was developed using a smaller liner, the small bore tools and compatible gravel-pack design for the smaller liner as well as the unusual use of an enhanced low-profile prepacked (ELP) screen were significant to the success of this completion. The unusual completion was run as planned. The gravel pack was successfully performed with returns throughout the treatment. The well is on line and performing better than expected. Introduction Innovative solutions to unexpected conditions often provide the industry with new "best-practice" procedures and opportunities to enlarge the scope of usage for proven equipment. In this case, an operator had planned a cased, slimhole completion that was to be approximately 10,000-ft deep with a 5-in. liner. The formation was sandstone, and thus, gravel packing would be required. The drilling of the well had proceeded as planned, but the liner stuck at 1500 feet from bottom. With the narrow size of the hole, a sidetrack appeared to be the only solution; however, the operator felt that this option was not acceptable and that unless another solution could be developed, the well project would have to be abandoned. The service provider felt that a new completion configuration could be developed to address the liner restrictions. To efficiently develop a solution, the operator and service company representatives met and formed a dedicated team to develop a process that would provide the perforation needs, solve the packer problem (since there was no 4-in. packer available), and perform the gravel pack satisfactorily from a service vessel. There were several problems that had to be resolved, including:How could the desired number of perforations be shot in the small casing What kind of screen should be used? How to reconfigure the completion since there was no packer available for a 4-in. liner How to coordinate the tool size versus casing clearances How to determine and addressthe effects the available space would have on the velocity of the treatment, and whether this would decrease probability of an affective gravel pack? When the liner became stuck, the operator's main concern had been that the well would have to be sidetracked or sand control would have to be sacrificed. Neither solution appeared to be satisfactory. The primary functions of the team, therefore, were to develop a plan to complete using smaller equipment and to redesign the gravel pack to fit and be pumped around the smaller tools.