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Improving production and prediction of the flow regimes, pressure drop, and void fraction in the perforated horizontal wellbore

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dc.citedby0
dc.contributor.authorKareem H.J.en_US
dc.contributor.authorHasini H.en_US
dc.contributor.authorAbdulwahid M.A.en_US
dc.contributor.authorid57200120717en_US
dc.contributor.authorid6507435998en_US
dc.contributor.authorid55928539700en_US
dc.date.accessioned2024-10-14T03:17:50Z
dc.date.available2024-10-14T03:17:50Z
dc.date.issued2023
dc.description.abstractThis study aimed to investigate how oil production could be improved by experimenting with different distribution methods across multiple profiles. The authors tested five different profiles that included uniform radial airflow (explained in profile 1) and variable radial airflow (explained in profiles 2, 3, 4 and 5) in a perforated horizontal wellbore. In addition, the study predicted the behavior of total pressure drop, superficial mixture velocity and void fraction encountered in different flow patterns (bubble, slug, stratum and stratum wave flow). Flow patterns were predicted using ANSYS Fluent R3 with a borehole length of 3 m and an ID of 0.0381 m. This was designed with 12 perforations opening vertically at the wellbore with a phase angle of 180 and a perforation density of 4 shots per foot to simulate the complex flow in a horizontal wellbore. In the perforated section, there was a fluctuation in the behavior of the parameters, while in the non-perforated section, the behavior remained constant. The behavior of the total pressure drop, the superficial velocity mixtures and the void fraction were also reasonably uniform in profile 1 in the perforated section. In contrast, they were irregular in the other profiles. In profiles 2, 3, 4 and 5, the behavior of the mixture superficial velocity and void fraction was inverse to the total pressure drop. Note that all theoretically calculated pressure drop modes increased as the Reynolds number of the mixture increased. The liquid and air product increased with increasing Reynolds number of mixture flow in the profiles. In contrast, in profile 1, lower production was obtained through all flow patterns due to the influence of the mixture pressure and the friction factor. The Vogels method was used to calculate maximum production from the horizontal wellbore. The convergence between experimental and numerical results was good during all cases (flow patterns), with some difference in the static pressure drop behaviuor occurring during flow patterns (bubble, dispersed bubble and slug flow). � 2023 Elsevier B.V.en_US
dc.description.natureFinalen_US
dc.identifier.ArtNo112324
dc.identifier.doi10.1016/j.nucengdes.2023.112324
dc.identifier.scopus2-s2.0-85159113208
dc.identifier.urihttps://www.scopus.com/inward/record.uri?eid=2-s2.0-85159113208&doi=10.1016%2fj.nucengdes.2023.112324&partnerID=40&md5=1db2516472c33eecc95c918939f6fee0
dc.identifier.urihttps://irepository.uniten.edu.my/handle/123456789/34066
dc.identifier.volume409
dc.publisherElsevier Ltden_US
dc.sourceScopus
dc.sourcetitleNuclear Engineering and Design
dc.subjectFlow pattern
dc.subjectFluid film thickness
dc.subjectFriction factor
dc.subjectNumerical analysis
dc.subjectProduction
dc.subjectSuperficial mixture velocity
dc.subjectTotal pressure drop
dc.subjectVoid fraction
dc.subjectBoreholes
dc.subjectDrops
dc.subjectFlow patterns
dc.subjectFriction
dc.subjectHorizontal wells
dc.subjectInverse problems
dc.subjectOil field equipment
dc.subjectOil wells
dc.subjectPressure drop
dc.subjectReynolds number
dc.subjectFlow regimes
dc.subjectFluid film thickness
dc.subjectFriction factors
dc.subjectHorizontal wellbores
dc.subjectMixture velocity
dc.subjectPerforated sections
dc.subjectReynold number
dc.subjectSuperficial mixture velocity
dc.subjectSuperficial velocity
dc.subjectTotal pressure drop
dc.subjectVoid fraction
dc.titleImproving production and prediction of the flow regimes, pressure drop, and void fraction in the perforated horizontal wellboreen_US
dc.typeArticleen_US
dspace.entity.typePublication
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