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N(2) Foam Flooding Combined with Gel Plugging for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory Experiments and Numerical Simulations
[Image: see text] The high-temperature reservoir (105 °C) in the Liubei block of Jidong Oilfield, with severe longitudinal heterogeneity, has entered a high water-cut stage. After a preliminary profile control, the water management of the oilfield still faces serious water channeling problems. To st...
Autores principales: | , , , , , , |
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Formato: | Online Artículo Texto |
Lenguaje: | English |
Publicado: |
American Chemical Society
2023
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Acceso en línea: | https://www.ncbi.nlm.nih.gov/pmc/articles/PMC10324386/ https://www.ncbi.nlm.nih.gov/pubmed/37426279 http://dx.doi.org/10.1021/acsomega.3c02383 |
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author | Hao, Hongda Li, Jiaxin Deng, Song Xian, Bihua Tang, Zheng Yang, Shuo Hou, Jirui |
author_facet | Hao, Hongda Li, Jiaxin Deng, Song Xian, Bihua Tang, Zheng Yang, Shuo Hou, Jirui |
author_sort | Hao, Hongda |
collection | PubMed |
description | [Image: see text] The high-temperature reservoir (105 °C) in the Liubei block of Jidong Oilfield, with severe longitudinal heterogeneity, has entered a high water-cut stage. After a preliminary profile control, the water management of the oilfield still faces serious water channeling problems. To strengthen water management, N(2) foam flooding combined with gel plugging for enhanced oil recovery was studied. In this work, considering a high-temperature reservoir of 105 °C, a composite foam system and starch graft gel system with high temperature resistance were screened out, and displacement experiments in one-dimensional heterogeneous cores were carried out. Through the three-dimensional experimental model and numerical model of a 5-spot well pattern, physical experiments and numerical simulations were carried out respectively to study water control and oil increase. The experimental results showed that the foam composite system had good temperature resistance up to 140 °C and oil resistance up to 50% oil saturation and was helpful to adjust the heterogeneous profile in a high temperature of 105 °C. The starch graft gel system had good injection performance, with a solution viscosity of 18.15 mPa·s, and its gel strength could effectively seal the high-permeability layer, with a gel viscosity of 34950.92 mPa·s. The displacement test results showed that after a preliminary implementation of N(2) foam flooding, N(2) foam flooding combined with gel plugging could still improve oil recovery by 5.26%. Compared with preliminary N(2) foam flooding, gel plugging could control the water channeling in the high-permeability zone near the production wells. The combination of foam and gel made N(2) foam flooding and subsequent waterflooding divert to flow mainly along the low-permeability layer, which was conducive to enhance water management and improve oil recovery. This method can be used as an effective technology to manage similar heterogeneous reservoirs. |
format | Online Article Text |
id | pubmed-10324386 |
institution | National Center for Biotechnology Information |
language | English |
publishDate | 2023 |
publisher | American Chemical Society |
record_format | MEDLINE/PubMed |
spelling | pubmed-103243862023-07-07 N(2) Foam Flooding Combined with Gel Plugging for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory Experiments and Numerical Simulations Hao, Hongda Li, Jiaxin Deng, Song Xian, Bihua Tang, Zheng Yang, Shuo Hou, Jirui ACS Omega [Image: see text] The high-temperature reservoir (105 °C) in the Liubei block of Jidong Oilfield, with severe longitudinal heterogeneity, has entered a high water-cut stage. After a preliminary profile control, the water management of the oilfield still faces serious water channeling problems. To strengthen water management, N(2) foam flooding combined with gel plugging for enhanced oil recovery was studied. In this work, considering a high-temperature reservoir of 105 °C, a composite foam system and starch graft gel system with high temperature resistance were screened out, and displacement experiments in one-dimensional heterogeneous cores were carried out. Through the three-dimensional experimental model and numerical model of a 5-spot well pattern, physical experiments and numerical simulations were carried out respectively to study water control and oil increase. The experimental results showed that the foam composite system had good temperature resistance up to 140 °C and oil resistance up to 50% oil saturation and was helpful to adjust the heterogeneous profile in a high temperature of 105 °C. The starch graft gel system had good injection performance, with a solution viscosity of 18.15 mPa·s, and its gel strength could effectively seal the high-permeability layer, with a gel viscosity of 34950.92 mPa·s. The displacement test results showed that after a preliminary implementation of N(2) foam flooding, N(2) foam flooding combined with gel plugging could still improve oil recovery by 5.26%. Compared with preliminary N(2) foam flooding, gel plugging could control the water channeling in the high-permeability zone near the production wells. The combination of foam and gel made N(2) foam flooding and subsequent waterflooding divert to flow mainly along the low-permeability layer, which was conducive to enhance water management and improve oil recovery. This method can be used as an effective technology to manage similar heterogeneous reservoirs. American Chemical Society 2023-06-16 /pmc/articles/PMC10324386/ /pubmed/37426279 http://dx.doi.org/10.1021/acsomega.3c02383 Text en © 2023 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 | Hao, Hongda Li, Jiaxin Deng, Song Xian, Bihua Tang, Zheng Yang, Shuo Hou, Jirui N(2) Foam Flooding Combined with Gel Plugging for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory Experiments and Numerical Simulations |
title | N(2) Foam
Flooding Combined with Gel Plugging
for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory
Experiments and Numerical Simulations |
title_full | N(2) Foam
Flooding Combined with Gel Plugging
for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory
Experiments and Numerical Simulations |
title_fullStr | N(2) Foam
Flooding Combined with Gel Plugging
for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory
Experiments and Numerical Simulations |
title_full_unstemmed | N(2) Foam
Flooding Combined with Gel Plugging
for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory
Experiments and Numerical Simulations |
title_short | N(2) Foam
Flooding Combined with Gel Plugging
for Enhanced Oil Recovery in High-Temperature Reservoirs: Laboratory
Experiments and Numerical Simulations |
title_sort | n(2) foam
flooding combined with gel plugging
for enhanced oil recovery in high-temperature reservoirs: laboratory
experiments and numerical simulations |
url | https://www.ncbi.nlm.nih.gov/pmc/articles/PMC10324386/ https://www.ncbi.nlm.nih.gov/pubmed/37426279 http://dx.doi.org/10.1021/acsomega.3c02383 |
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