Porosity and permeability alteration around wellbore during injection process

Enhanced oil recovery (EOR) methods were processed to increase the amount of oil extracted from a reservoir after primary and secondary recoveries, typically by injecting water or gas. Fluid injection has been vastly applied in oil wells as a simple and effective EOR method. Rocks are a combination...

Full description

Main Authors: Bataee, M., Irawan, S.
Format: Article
Institution: Universiti Teknologi Petronas
Record Id / ISBN-0: utp-eprints.21812 /
Published: American Society of Civil Engineers (ASCE) 2018
Online Access: https://www.scopus.com/inward/record.uri?eid=2-s2.0-85037529259&doi=10.1061%2f%28ASCE%29GM.1943-+5622.0001051&partnerID=40&md5=4313048969ce3d4e5fa3e21d69ca9e81
http://eprints.utp.edu.my/21812/
Tags: Add Tag
No Tags, Be the first to tag this record!
id utp-eprints.21812
recordtype eprints
spelling utp-eprints.218122018-10-19T06:26:55Z Porosity and permeability alteration around wellbore during injection process Bataee, M. Irawan, S. Enhanced oil recovery (EOR) methods were processed to increase the amount of oil extracted from a reservoir after primary and secondary recoveries, typically by injecting water or gas. Fluid injection has been vastly applied in oil wells as a simple and effective EOR method. Rocks are a combination of different materials that exhibit poroelastic response. The amount of stress indexed by pore pressure depends on pore content. Rock stress around a wellbore is a function of wellbore fluid flow. On the other hand, fluid flow is the function of porosity and permeability. Nevertheless, porosity and permeability alter as stress changes. Therefore, a coupling method should be used. The purpose of this study is to propose a model to find corrected stresses and calculate the change in porosity and permeability after injection. This study focuses on wellbore results. Effective parameters, such as pressure, temperature, saturation, and stress, were obtained for the multiphase flow condition using mathematical modeling. Moreover, pressure and saturation are solved using the finite-difference method, whereas the finite-volume method is applied to obtain rock stresses. The iterative coupling method is used to improve the accuracy of results. The results of the study showed how porosity and permeability will change after drilling around the well and how they will increase during injection. The results expressed the corrected distribution of stress values after injection. Porosity and permeability were reduced from their original values after drilling; nonetheless, their values had increased after injection but not equally around the wellbore. Moreover, it was concluded that the change in porosity and permeability by injection was more significant in low-porosity formations. © 2017 American Society of Civil Engineers. American Society of Civil Engineers (ASCE) 2018 Article PeerReviewed https://www.scopus.com/inward/record.uri?eid=2-s2.0-85037529259&doi=10.1061%2f%28ASCE%29GM.1943-+5622.0001051&partnerID=40&md5=4313048969ce3d4e5fa3e21d69ca9e81 Bataee, M. and Irawan, S. (2018) Porosity and permeability alteration around wellbore during injection process. International Journal of Geomechanics, 18 (2). http://eprints.utp.edu.my/21812/
institution Universiti Teknologi Petronas
collection UTP Institutional Repository
description Enhanced oil recovery (EOR) methods were processed to increase the amount of oil extracted from a reservoir after primary and secondary recoveries, typically by injecting water or gas. Fluid injection has been vastly applied in oil wells as a simple and effective EOR method. Rocks are a combination of different materials that exhibit poroelastic response. The amount of stress indexed by pore pressure depends on pore content. Rock stress around a wellbore is a function of wellbore fluid flow. On the other hand, fluid flow is the function of porosity and permeability. Nevertheless, porosity and permeability alter as stress changes. Therefore, a coupling method should be used. The purpose of this study is to propose a model to find corrected stresses and calculate the change in porosity and permeability after injection. This study focuses on wellbore results. Effective parameters, such as pressure, temperature, saturation, and stress, were obtained for the multiphase flow condition using mathematical modeling. Moreover, pressure and saturation are solved using the finite-difference method, whereas the finite-volume method is applied to obtain rock stresses. The iterative coupling method is used to improve the accuracy of results. The results of the study showed how porosity and permeability will change after drilling around the well and how they will increase during injection. The results expressed the corrected distribution of stress values after injection. Porosity and permeability were reduced from their original values after drilling; nonetheless, their values had increased after injection but not equally around the wellbore. Moreover, it was concluded that the change in porosity and permeability by injection was more significant in low-porosity formations. © 2017 American Society of Civil Engineers.
format Article
author Bataee, M.
Irawan, S.
spellingShingle Bataee, M.
Irawan, S.
Porosity and permeability alteration around wellbore during injection process
author_sort Bataee, M.
title Porosity and permeability alteration around wellbore during injection process
title_short Porosity and permeability alteration around wellbore during injection process
title_full Porosity and permeability alteration around wellbore during injection process
title_fullStr Porosity and permeability alteration around wellbore during injection process
title_full_unstemmed Porosity and permeability alteration around wellbore during injection process
title_sort porosity and permeability alteration around wellbore during injection process
publisher American Society of Civil Engineers (ASCE)
publishDate 2018
url https://www.scopus.com/inward/record.uri?eid=2-s2.0-85037529259&doi=10.1061%2f%28ASCE%29GM.1943-+5622.0001051&partnerID=40&md5=4313048969ce3d4e5fa3e21d69ca9e81
http://eprints.utp.edu.my/21812/
_version_ 1741196524839239680
score 11.62408

Similar Items