A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells

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...

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Main Authors: James O. Adeleye, Olugbenga Olamigoke, Oluseun T. Mumuni
Format: Article
Language:English
Published: SpringerOpen 2020-10-01
Series:Journal of Petroleum Exploration and Production Technology
Subjects:
Online Access:https://doi.org/10.1007/s13202-020-01014-z
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author James O. Adeleye
Olugbenga Olamigoke
Oluseun T. Mumuni
author_facet James O. Adeleye
Olugbenga Olamigoke
Oluseun T. Mumuni
author_sort James O. Adeleye
collection DOAJ
description 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.
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spelling doaj.art-9ca1f39cd0ca4909b5980dcca552824b2024-04-21T11:09:45ZengSpringerOpenJournal of Petroleum Exploration and Production Technology2190-05582190-05662020-10-0111134735710.1007/s13202-020-01014-zA predictive protocol to obtain maximum water-free oil production rate for perforated vertical wellsJames O. Adeleye0Olugbenga Olamigoke1Oluseun T. Mumuni2Society of Petroleum EngineersDepartment of Chemical and Petroleum Engineering, Faculty of Engineering, University of LagosDepartment of Petroleum ResourcesAbstract 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.https://doi.org/10.1007/s13202-020-01014-zComputational modelPerforation strategyMaximum water-free oil production ratePerforation parametersWater breakthrough
spellingShingle James O. Adeleye
Olugbenga Olamigoke
Oluseun T. Mumuni
A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
Journal of Petroleum Exploration and Production Technology
Computational model
Perforation strategy
Maximum water-free oil production rate
Perforation parameters
Water breakthrough
title A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
title_full A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
title_fullStr A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
title_full_unstemmed A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
title_short A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells
title_sort predictive protocol to obtain maximum water free oil production rate for perforated vertical wells
topic Computational model
Perforation strategy
Maximum water-free oil production rate
Perforation parameters
Water breakthrough
url https://doi.org/10.1007/s13202-020-01014-z
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