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Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs
[Image: see text] The upper Wuerhe formation in the Mahu-1 play is a tight conglomerate reservoir that has characteristics of low porosity and low permeability. During the early stage of field development, it has been noticed that horizontal wells typically have a high flowback ratio and an extremel...
Autores principales: | , , , , , , |
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Formato: | Online Artículo Texto |
Lenguaje: | English |
Publicado: |
American Chemical Society
2022
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Acceso en línea: | https://www.ncbi.nlm.nih.gov/pmc/articles/PMC8867474/ https://www.ncbi.nlm.nih.gov/pubmed/35224352 http://dx.doi.org/10.1021/acsomega.1c06140 |
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author | Li, Jiayan Zhang, Kun Cheng, Ning Xing, Zhicheng Wang, Song Wang, Bin Liang, Tianbo |
author_facet | Li, Jiayan Zhang, Kun Cheng, Ning Xing, Zhicheng Wang, Song Wang, Bin Liang, Tianbo |
author_sort | Li, Jiayan |
collection | PubMed |
description | [Image: see text] The upper Wuerhe formation in the Mahu-1 play is a tight conglomerate reservoir that has characteristics of low porosity and low permeability. During the early stage of field development, it has been noticed that horizontal wells typically have a high flowback ratio and an extremely low oil production rate during the early production, and this is likely attributed to the water–rock interaction that causes the closure of generated hydraulic fractures. In this study, a stabilizer and its dosage in a fracturing fluid are optimized, and its effect on clay antiswelling and rock stabilization is evaluated. Experimental results indicate that a mixture of a salt and an inorganic cationic polymer can effectively inhibit the water–rock reaction by minimizing the clay swelling and compressing the electric double layer on the rock surface. The antiswelling rate of montmorillonite can reach 93.56%, and that of the reservoir rock powder can reach 75.32%. Meanwhile, Brazilian splitting tests are conducted to evaluate the mechanical property change of reservoir rocks before and after being submerged in fracturing fluids with different stabilizers. Compared to 4% KCl, which is currently used in the field, the new formula can enhance the breakdown pressure by more than 10% without increasing the cost. The findings of this work provide a solution for fracturing water-sensitive reservoirs and also establish a set of laboratory methods for optimizing stabilizers as fracturing fluid additives. |
format | Online Article Text |
id | pubmed-8867474 |
institution | National Center for Biotechnology Information |
language | English |
publishDate | 2022 |
publisher | American Chemical Society |
record_format | MEDLINE/PubMed |
spelling | pubmed-88674742022-02-25 Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs Li, Jiayan Zhang, Kun Cheng, Ning Xing, Zhicheng Wang, Song Wang, Bin Liang, Tianbo ACS Omega [Image: see text] The upper Wuerhe formation in the Mahu-1 play is a tight conglomerate reservoir that has characteristics of low porosity and low permeability. During the early stage of field development, it has been noticed that horizontal wells typically have a high flowback ratio and an extremely low oil production rate during the early production, and this is likely attributed to the water–rock interaction that causes the closure of generated hydraulic fractures. In this study, a stabilizer and its dosage in a fracturing fluid are optimized, and its effect on clay antiswelling and rock stabilization is evaluated. Experimental results indicate that a mixture of a salt and an inorganic cationic polymer can effectively inhibit the water–rock reaction by minimizing the clay swelling and compressing the electric double layer on the rock surface. The antiswelling rate of montmorillonite can reach 93.56%, and that of the reservoir rock powder can reach 75.32%. Meanwhile, Brazilian splitting tests are conducted to evaluate the mechanical property change of reservoir rocks before and after being submerged in fracturing fluids with different stabilizers. Compared to 4% KCl, which is currently used in the field, the new formula can enhance the breakdown pressure by more than 10% without increasing the cost. The findings of this work provide a solution for fracturing water-sensitive reservoirs and also establish a set of laboratory methods for optimizing stabilizers as fracturing fluid additives. American Chemical Society 2022-02-13 /pmc/articles/PMC8867474/ /pubmed/35224352 http://dx.doi.org/10.1021/acsomega.1c06140 Text en © 2022 The Authors. Published by American Chemical Society https://creativecommons.org/licenses/by-nc-nd/4.0/Permits non-commercial access and re-use, provided that author attribution and integrity are maintained; but does not permit creation of adaptations or other derivative works (https://creativecommons.org/licenses/by-nc-nd/4.0/). |
spellingShingle | Li, Jiayan Zhang, Kun Cheng, Ning Xing, Zhicheng Wang, Song Wang, Bin Liang, Tianbo Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs |
title | Optimization and Evaluation of Stabilizers for Tight
Water-Sensitive Conglomerate Reservoirs |
title_full | Optimization and Evaluation of Stabilizers for Tight
Water-Sensitive Conglomerate Reservoirs |
title_fullStr | Optimization and Evaluation of Stabilizers for Tight
Water-Sensitive Conglomerate Reservoirs |
title_full_unstemmed | Optimization and Evaluation of Stabilizers for Tight
Water-Sensitive Conglomerate Reservoirs |
title_short | Optimization and Evaluation of Stabilizers for Tight
Water-Sensitive Conglomerate Reservoirs |
title_sort | optimization and evaluation of stabilizers for tight
water-sensitive conglomerate reservoirs |
url | https://www.ncbi.nlm.nih.gov/pmc/articles/PMC8867474/ https://www.ncbi.nlm.nih.gov/pubmed/35224352 http://dx.doi.org/10.1021/acsomega.1c06140 |
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