A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
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ORIGINAL PAPER-PRODUCTION ENGINEERING
A predictive protocol to obtain maximum water‑free oil production rate for perforated vertical wells James O. Adeleye1 · Olugbenga Olamigoke2 · Oluseun T. Mumuni3 Received: 3 July 2020 / Accepted: 25 September 2020 © The Author(s) 2020
Abstract Producing an oilfield in a cost-effective way depends on how long water production could be delayed in the reservoir. Many flow mechanisms, correlations, and methods to calculate maximum water-free oil production rate have been published, However, those methods have generally failed to not consider the skin effect which affects the flow into the wellbore. In this paper, the semi-analytical perforation skin model as presented by Karakas and Tariq is incorporated into the Meyer and Garder correlation for critical oil rate from a perforated vertical well interval to obtain the maximum water-free oil production rate and optimal perforation parameters. The resulting coupled computational model is used to determine the sensitivity of the maximum water-free oil production rate to wellbore perforation parameters. Whilst an increase in perforation length and decrease in spacing between perforation increase the critical flow rate, an increase in perforation radius did not translate to higher productivity. The optimal perforation angles are 45° and 60°, however, for the data used in this work the maximum water-free oil rate of 23.2 std/d was obtained at 45° of phasing angle, 1 in of spacing between perforation, 0.36 in of perforation radius and 48 in of perforation length. Thus, the perforation strategy can be optimized prior to drilling and completion operations to improve productivity using the computational model presented in this work. Keywords Computational model · Perforation strategy · Maximum water-free oil production rate · Perforation parameters · Water breakthrough
Introduction An increase in the cost of production operations, environmental problems, reduction in depletion mechanism efficiency and processing of the produced water are major challenges to production and reservoir engineers. Oil or gas reservoirs will produce with increasing water cuts especially from zones with active underlying aquifers that tend to elevate the water–oil contact in the vicinity of the completion interval. This necessitates the determination of the maximum waterfree oil production rate that a completed well can deliver. The flow mechanisms, correlations and methods to calculate this critical rate have been developed for wells completed * Olugbenga Olamigoke [email protected] 1
Society of Petroleum Engineers, Lagos, Nigeria
2
Department of Chemical and Petroleum Engineering, Faculty of Engineering, University of Lagos, Lagos, Nigeria
3
Department of Petroleum Resources, Lagos, Nigeria
in a continuous pay zone with oil–water contact or gas-oil contact or both (Meyer and Garder 1954; Chierici et al. 1964; Høyland et al. 1989; Menouar and Hakim 1995; Zhang et al. 2011; Tabatabaei et al. 2012). Correlations have also been developed t
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