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Recent Advances in Reservoir Simulation and Carbon Utilization and Storage—2nd Edition

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H: Geo-Energy".

Deadline for manuscript submissions: 15 July 2025 | Viewed by 2180

Special Issue Editors

Dr. Wenchao Liu

E-Mail Website
Guest Editor
School of Civil and Resources and Engineering, University of Science and Technology Beijing, Beijing 100083, China
Interests: reservoir numerical simulation; applied mathematical modelling; nonlinear seepage flow mechanics in unconventional reservoirs
Special Issues, Collections and Topics in MDPI journals
Dr. Hai Sun

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: pore scale simulation in porous media; multiscale simulation of unconventional oil and gas reservoirs
Special Issues, Collections and Topics in MDPI journals
Dr. Daobing Wang

E-Mail Website
Guest Editor
College of Mechanical Engineering, Beijing Institute of Petrochemical Technology, Beijing 102699, China
Interests: hydraulic fracturing; rock mechanics; reduced-order modeling
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

With the increasing demand for fossil energy and the continuous progress of industrial technology, the development of unconventional oil and gas resources has become an important means of increasing oil and gas production worldwide. Unconventional oil and gas development technologies need to incorporate special seepage flow laws in unconventional oil and gas reservoirs (e.g., non-Darcy flow and multi-scale flow in naturally fractured tight reservoirs), so as to be effectively applied to practice and guide production. Reservoir simulation, including both physical and numerical simulation, is a very useful tool to uncover the seepage flow behavior in underground unconventional oil and gas reservoirs. Additionally, in order to achieve the goal of carbon neutrality, the utilization and underground storage of carbon dioxide in the development of both conventional and unconventional oil and gas resources has recently become a hot research topic, including CO2 fracturing technology of wellbores, enhanced oil recovery by CO2 flooding, CO2 geological storage, safety assessment of CO2 storage, etc.

This Special Issue aims to present and disseminate the most recent advances related to unconventional reservoir numerical simulation, unconventional reservoir physical simulation, and the utilization and underground storage of carbon dioxide in the development of petroleum reservoirs. 

Topics of interest for include the following:

  • Reservoir numerical/physical simulation;
  • Microscale and nanoscale fluid flow in unconventional reservoirs;
  • Multiscale pore structure characterization of unconventional reservoirs;
  • Application of microfluidics and nanofluidics experiments in unconventional reservoirs;
  • Multiscale simulation of oil and gas flow in unconventional reservoirs;
  • Seepage flow mechanics in unconventional reservoirs;
  • Unconventional petroleum reservoir modelling and numerical and analytical solution methods;
  • Hydraulic fracturing simulation;
  • Rock mechanical properties of unconventional reservoirs;
  • New fracturing technology, such as hydraulic fracturing with diverters, CO2 fracturing technology and liquid nitrogen fracturing;
  • Interaction between hydraulic fracture and natural fractures;
  • All aspects of the utilization and underground storage of carbon dioxide in the development of petroleum resources.

Dr. Wenchao Liu
Dr. Hai Sun
Dr. Daobing Wang
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • unconventional reservoir simulation
  • seepage flow mechanics
  • carbon dioxide
  • pore scale simulation
  • hydraulic fracturing simulation
  • rock mechanical
  • new fracturing technology
  • hydraulic fracture
  • natural fractures

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Related Special Issue

Published Papers (3 papers)

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Research

19 pages, 2274 KiB  
Article
Construction and Application of a Coupled Temperature and Pressure Model for CO2 Injection Wells Considering Gas Composition
by Hang Lai, Peng Chen, Lingang Lv and Song Lu
Energies 2025, 18(5), 1238; https://doi.org/10.3390/en18051238 - 3 Mar 2025
Viewed by 589
Abstract
Accurate prediction of the temperature and pressure fields in carbon dioxide (CO2) injection wells is critical for enhancing oil recovery efficiency and ensuring safe carbon sequestration. At present, the prediction model generally assumes that CO2 is pure and does not [...] Read more.
Accurate prediction of the temperature and pressure fields in carbon dioxide (CO2) injection wells is critical for enhancing oil recovery efficiency and ensuring safe carbon sequestration. At present, the prediction model generally assumes that CO2 is pure and does not consider the influence of impurities in CO2 components. This study takes into account the common impurities, such as air and various alkanes in CO2, and uses Refprop 9.0 software to calculate the physical parameters of the mixture. A comprehensive coupling model was developed to account for axial heat conduction, convective heat transfer, frictional heat generation, the soup coke effect, pressure work, and gas composition. The model was solved iteratively using numerical methods. We validated the accuracy of the calculated results by comparing our model with the Ramey model using measured injection well data. Compared with the measured bottom hole temperature and pressure data, the error percentage of our model to predict the bottom hole temperature and pressure is less than 1%, while the error percentage of Ramey model to predict the bottom hole temperature and pressure is 5.15% and 1.33%, respectively. Our model has higher bottom hole temperature and pressure prediction accuracy than the Ramey model. In addition, we use the model to simulate the influence of different injection parameters on wellbore temperature and pressure and consider the influence of different gas components. Each injection parameter uses three components. Based on the temperature and pressure data calculated by the model simulation, the phase state of CO2 was analyzed. The results show that the impurities in CO2 have a great influence on the predicted wellbore pressure, critical temperature, and critical pressure. In the process of CO2 injection, increasing the injection pressure can significantly increase the bottom hole pressure, and changing the injection rate can adjust the bottom hole temperature. The research provides valuable insights for CO2 sequestration and enhanced oil recovery (EOR). Full article
(This article belongs to the Special Issue Recent Advances in Reservoir Simulation and Carbon Utilization and Storage—2nd Edition)
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19 pages, 5989 KiB  
Article
Effect of Dynamic Injection Velocity and Mixed Wettability on Two-Phase Flow Behavior in Porous Media: A Numerical Study
by Wei Hui, Le Wang, Xurui Liu and Yueshe Wang
Energies 2025, 18(4), 879; https://doi.org/10.3390/en18040879 - 12 Feb 2025
Viewed by 670
Abstract
Immiscible displacement in porous media is a crucial microscale flow phenomenon in many fields, necessitating an understanding of the flow mechanisms under dynamic injection velocity and mixing wettability to predict and affect this flow accurately. Initially, a dynamic injection velocity method and a [...] Read more.
Immiscible displacement in porous media is a crucial microscale flow phenomenon in many fields, necessitating an understanding of the flow mechanisms under dynamic injection velocity and mixing wettability to predict and affect this flow accurately. Initially, a dynamic injection velocity method and a computational domain model considering non-dominant/dominant wetting angles were proposed. Then, microscale flow phenomena were modeled in a pore throat structure and doublet geometry under mixed wetting conditions. Finally, the influence of dynamic injection velocity and mixed wettability on microscale flow were investigated using numerical simulations. The results indicate that when stepwise and piecewise linear changes in injection velocity are observed, unlike continuous injection, two preferential displacement pathways are predominantly formed in the porous media. As the difference between the maximum and minimum injection velocity increases, the recovery efficiency initially decreases and then increases. Recovery efficiency is higher under piecewise linear injection velocity changes. The non-dominant wetting angle determines the distribution and flow of oil-water two-phase systems in porous media. With a dominant controlling wetting angle of 45°, as the non-dominant wetting angle increases, the flow phenomenon changes from one preferential pathway in the back region (30°, 45°) to two preferential pathways (60°, 90°, 120°) and then to one preferential pathway in the middle porous media (150°). As the degree of the non-dominant wetting angle increases, the recovery efficiency first increases and then decreases, with a maximum and minimum difference of 13.6%. Full article
(This article belongs to the Special Issue Recent Advances in Reservoir Simulation and Carbon Utilization and Storage—2nd Edition)
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21 pages, 6973 KiB  
Article
Comprehensive Characterization and Impact Analysis of Interlayers on CO2 Flooding in Low-Permeability Sandstone Reservoirs
by Taskyn Abitkazy, Lin Yan, Khaled Albriki, Bahedaer Baletabieke, Dawei Yuan, Yingfu He and Akhan Sarbayev
Energies 2025, 18(3), 593; https://doi.org/10.3390/en18030593 - 27 Jan 2025
Viewed by 694
Abstract
In low-permeability sandstone reservoirs (LPSR), impermeable interlayers significantly challenge carbon capture, utilization, and storage (CCUS) and enhance oil recovery (CO2-EOR) processes by creating complex, discontinuous flow units. This study aims to address these challenges through a comprehensive multi-faceted approach integrating geological [...] Read more.
In low-permeability sandstone reservoirs (LPSR), impermeable interlayers significantly challenge carbon capture, utilization, and storage (CCUS) and enhance oil recovery (CO2-EOR) processes by creating complex, discontinuous flow units. This study aims to address these challenges through a comprehensive multi-faceted approach integrating geological and microscopic analyses, including core analysis, reservoir petrography, field emission-scanning electron microscopy (FE-SEM), energy dispersive spectroscopy (EDS), and well-logging response analysis, and utilizing three-dimensional (3D) geological modeling. The current comprehensive investigation systematically characterizes interlayer types, petrophysical properties, thickness, connectivity, and their spatial distribution in the reservoir unit. Numerical simulations were conducted to assess the sealing efficiency and the impact of various interlayer materials on CO2 flooding over a 10-year period. Results indicate the presence of petrophysical and argillaceous interlayers, with optimal sealing occurring in petrophysical barriers ≥ 4 m and argillaceous barriers ≥ 1.5 m thick. CO2 leakage occurs through preferential pathways that emerge in a side-to-middle and bottom-to-top direction in interbeds, with multidirectional pathways showing greater leakage at the bottom compared to the upper side within barriers. Increased interlayer thickness constraints CO2 breakthrough but reduces vertical flooding area and production ratio compared to homogeneous reservoirs. Augmented interbed thickness and area mitigate CO2 breakthrough time while constraining gravity override and dispersion effects, enhancing horizontal oil displacement. These novel findings provide crucial insights for optimizing CCUS-EOR strategies in LPSR, offering a robust theoretical foundation for future applications and serving as a key reference for CO2 utilization in challenging geological settings of LPSR worldwide. Full article
(This article belongs to the Special Issue Recent Advances in Reservoir Simulation and Carbon Utilization and Storage—2nd Edition)
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