Fuxa, Jason (Baker Hughes) | Di Giampaolo, Paolo (Baker Hughes) | Ferrara, Giovanni (ENI) | Di Pietro, Mario (Baker Hughes) | Sportelli, Marco (ENI) | Ripa, Giuseppe (ENI) | Di Campli, Antonio (Baker Hughes)
This paper details a field application of Shaped Memory Polymer (SMP) material for sand management delivering an innovative approach for sand control completions. The use of the technology has enabled profitable exploitation of residual reserves in a mature gas field offshore Adriatic Sea. The paper reviews details of the field deployment, with both economic and well performance results described.
The Barbara Field was discovered in 1971 and 102 wells have been drilled to date. The trap is a very gentle, slightly asymmetrical anticline made by Pleistocene sandy turbidites,sedimented on the underlying carbonate substrate. Methane gas bearing layers have been sealed by several argillaceous intercalations that worked also as the source rocks of this multilayer reservoir. The sandy layers in this Pleistocene sequence, Carola Formation, have thickness ranging from few centimeters up to some meters, and porosity from 22 up to 33%. Isolation of multiple gas-water contacts and fines production have been two crucial issues while producing the field.
Since 2000, all seven Barbara platforms have required workovers by means of performing sidetracks. Due to the reservoir characteristics, the well interventions have been completed with multi-layer, stacked cased-hole sand control completions. Despite a continuous improvement of procedures and technique, the traditional sand control methods have been efficient but were no longer profitable, due to challenging market conditions.
An open-hole completion using SMP combined with zonal isolation and selective production has proved to be an effective alternative to cased-hole sand control. This novel completion approach resulted in a significant reduction in both cost and rig time. It is estimated that nearly two weeks of rig time was saved and an overall workover cost reduction of approximately 35%, with further efficiencies to be realized on upcoming deployments. To date, the completion has proved to be an effective sand control method, with no produced solids, no plugging effect, and gas production that has met expectations.
Copyright 2006, Society of Petroleum Engineers This paper was prepared for presentation at the 2006 SPE/ICoTA Coiled Tubing and Well Intervention Conference and Exhibition held in The Woodlands, TX, U.S.A., 4-5 April 2006. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes 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 where and by whom the paper was presented. Abstract This paper will present the results of an extensive pipe cutting campaign in the Adriatic Sea for a major Italian operator, where previous pipe cutting tools failed and where explosive severing tools were not permitted for offshore operations.
Ripa, Giuseppe (Eni Exploration & Production Div.) | Ligrone, Angelo (Eni Exploration & Production Div.) | Zamparini, Angelo (Eni Exploration & Production Div.) | Sportelli, Marco (Eni Exploration & Production Div.) | Mathis, Stephen P. (Baker Oil Tools) | Conte, Antonio (Baker Oil Tools)
When revitalizing mature oil or gas fields, the ability to maximizeproductivity while minimizing operating costs is critical.Achieving thesegoals becomes more challenging where sand control is required.This isespecially true in connection with a complex reservoir lithology, which leadsto a variety of fracture and pore pressure gradients and premature waterbreakthrough. In addition, reduced deliverability resulting from pressuredepletion presents additional complications related to achieving acceptableproject economics.
The Barbara field, located in the central Adriatic Sea, is an example ofthis type of reservoir.For this project, a dedicated work team wasassigned to identify and implement the solutions to improve field performancethrough continuous operations optimization. The Barbara field consists ofstacked pay sections that have been depleted since the early 1980s.Toachieve favorable economics, techniques had to be used that would do both:maximize the deliverability of each well and minimize operational costs.
This paper reviews the Barbara field workover program.The evolution oftechniques, equipment, and products leading to enhanced productivity whilesubstantially reducing costs is described.The fluid systems and operationprocedures designed to optimize frac-pack geometry are discussed.Inaddition, the one-trip multizone gravel-pack assemblies are described thatallow multiple zones to be individually fracture packed in a single run, thusproviding significant rig-time reductions without sacrificing completionefficiency.Finally, the complex nature of this reservoir dictates theneed for a variety of completion techniques.This means that fracturepacking was not necessarily an option for all zones.For the intervals atwhich fracturing was not employed, productivity still needed to bemaximized.To accomplish this goal, perforation tunnel-cleanup procedureshave been optimized.
Copyright 2005, Society of Petroleum Engineers This paper was prepared for presentation at the SPE European Formation Damage Conference held in Scheveningen, The Netherlands, 25-27 May 2005. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper, as presented, have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of Petroleum Engineers.