Cover Image

Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves

Understanding the invasion and flowback processes of water, as the main source of hydraulic fracking fluid, is crucial for the proper evaluation and development of complex gas shale formations. Direct measurements of full gas-water relative permeability and capillary pressure curves by steady-state...

Full description

Saved in:
Bibliographic Details
Main Authors: Sharifigaliuk, Hamid, Mahmood, Syed Mohammad, Zoveidavianpoor, Mansoor, Zivar, Davood, Afolabi, Funsho Ayobami
Format: Article
Published: American Chemical Society 2023
Subjects:
TP Chemical technology
Online Access:http://eprints.utm.my/106749/
http://dx.doi.org/10.1021/acs.energyfuels.3c01513
Tags: Add Tag
No Tags, Be the first to tag this record!
id my.utm.106749
record_format eprints
spelling my.utm.1067492024-07-28T06:25:38Z http://eprints.utm.my/106749/ Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves Sharifigaliuk, Hamid Mahmood, Syed Mohammad Zoveidavianpoor, Mansoor Zivar, Davood Afolabi, Funsho Ayobami TP Chemical technology Understanding the invasion and flowback processes of water, as the main source of hydraulic fracking fluid, is crucial for the proper evaluation and development of complex gas shale formations. Direct measurements of full gas-water relative permeability and capillary pressure curves by steady-state or unsteady-state techniques are not feasible in ultralow permeability shales. Therefore, the objective of this study is to investigate the dynamic rock-fluid properties of a Mancos shale sample by mimicking water imbibition and flowback experiments. To do so, a water injection experiment was done and tried to measure the flowback. After that, history matching on the experimental data of the water injection and flowback process was done to predict gas-water relative permeability data and capillary pressure curves. Low water flowback was observed, which insists on water entrapment in shale rocks. The results show a high threshold pressure and meaningful relative permeability of water, which can reduce the gas production rate dramatically. The saturation profiles show a high percentage of water in the invaded zone (>75%); however, the continuous imbibition of water with time (increase in shut-in time) helps the front of the invasion zone to move further deep into the shale, which enhances gas production. The S-shape gas relative permeability curve most likely represents the actual trend of the curve. An optimum shut-in time was predicted, which enables us to avoid delays in starting production operations. American Chemical Society 2023 Article PeerReviewed Sharifigaliuk, Hamid and Mahmood, Syed Mohammad and Zoveidavianpoor, Mansoor and Zivar, Davood and Afolabi, Funsho Ayobami (2023) Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves. Energy and Fuels, 37 (16). pp. 11928-11941. ISSN 0887-0624 http://dx.doi.org/10.1021/acs.energyfuels.3c01513 DOI : 10.1021/acs.energyfuels.3c01513
institution Universiti Teknologi Malaysia
building UTM Library
collection Institutional Repository
continent Asia
country Malaysia
content_provider Universiti Teknologi Malaysia
content_source UTM Institutional Repository
url_provider http://eprints.utm.my/
topic TP Chemical technology
spellingShingle TP Chemical technology
Sharifigaliuk, Hamid
Mahmood, Syed Mohammad
Zoveidavianpoor, Mansoor
Zivar, Davood
Afolabi, Funsho Ayobami
Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
description Understanding the invasion and flowback processes of water, as the main source of hydraulic fracking fluid, is crucial for the proper evaluation and development of complex gas shale formations. Direct measurements of full gas-water relative permeability and capillary pressure curves by steady-state or unsteady-state techniques are not feasible in ultralow permeability shales. Therefore, the objective of this study is to investigate the dynamic rock-fluid properties of a Mancos shale sample by mimicking water imbibition and flowback experiments. To do so, a water injection experiment was done and tried to measure the flowback. After that, history matching on the experimental data of the water injection and flowback process was done to predict gas-water relative permeability data and capillary pressure curves. Low water flowback was observed, which insists on water entrapment in shale rocks. The results show a high threshold pressure and meaningful relative permeability of water, which can reduce the gas production rate dramatically. The saturation profiles show a high percentage of water in the invaded zone (>75%); however, the continuous imbibition of water with time (increase in shut-in time) helps the front of the invasion zone to move further deep into the shale, which enhances gas production. The S-shape gas relative permeability curve most likely represents the actual trend of the curve. An optimum shut-in time was predicted, which enables us to avoid delays in starting production operations.
format Article
author Sharifigaliuk, Hamid
Mahmood, Syed Mohammad
Zoveidavianpoor, Mansoor
Zivar, Davood
Afolabi, Funsho Ayobami
author_facet Sharifigaliuk, Hamid
Mahmood, Syed Mohammad
Zoveidavianpoor, Mansoor
Zivar, Davood
Afolabi, Funsho Ayobami
author_sort Sharifigaliuk, Hamid
title Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
title_short Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
title_full Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
title_fullStr Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
title_full_unstemmed Experimental and modeling study of water imbibition and flowback in shale: Prediction of relative permeability and capillary pressure curves
title_sort experimental and modeling study of water imbibition and flowback in shale: prediction of relative permeability and capillary pressure curves
publisher American Chemical Society
publishDate 2023
url http://eprints.utm.my/106749/
http://dx.doi.org/10.1021/acs.energyfuels.3c01513
_version_ 1805880862853562368
score 13.211869

Similar Items