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Processes
Special Issues
Advances in Oil and Gas Reservoir Modeling and Simulation
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Advances in Oil and Gas Reservoir Modeling and Simulation

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Energy Systems".

Deadline for manuscript submissions: 30 September 2025 | Viewed by 1759

Special Issue Editors

Prof. Dr. Fathi Boukadi

E-Mail Website
Guest Editor
Department of Petroleum Engineering, The University of Louisiana, College of Engineering, Lafayette, LA 70503, USA
Interests: reservoir engineering (simulation of CO2 transport and sequestration); data analysis/analytics; machine learning
Dr. Talal Gamadi

E-Mail Website
Guest Editor
Bob L. Herd Department of Petroleum Engineering, Texas Tech University, P.O. Box 43111, Lubbock, TX 79409-3111, USA
Interests: reservoir engineering application (well testing analysis, MBE, decline curve analysis, etc.); EOR applications in conventional and unconventional reservoirs; reservoir simulation modeling (CMG, Petrel, and eclipse simulators); design and evaluation of hydraulic fracture stimulation treatments
Prof. Dr. Abdulrazag Zekri

E-Mail Website
Guest Editor
Department of Chemical and Petroleum Engineering, United Arab Emirates University, Al Ain, United Arab Emirates
Interests: enhanced oil recovery; environmental problems associated with oil and gas production; fluid flow in porous media
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Carbon dioxide (CO2) sequestration is a pivotal strategy in combating climate change, involving the capture and long-term storage of CO2 in geological formations. Techniques such as structural, residual, dissolution, and mineral trapping ensure secure storage, as demonstrated by case studies like Norway's Sleipner Project and the Illinois Basin in the U.S.

Plume propagation, or the subsurface movement of injected CO2, is also critical to understanding containment and pressure dynamics. Advanced numerical modeling and monitoring techniques, including time-lapse seismic imaging and tracer studies, have successfully tracked plume behavior in projects like Sleipner and Australia's Otway Project.

CO2-enhanced oil recovery (CO2-EOR) integrates sequestration with industrial applications, using CO2 to improve oil recovery while permanently trapping residual CO2. Projects such as Canada’s Weyburn and U.S. operations in the Permian Basin highlighted its dual benefits and challenges, including balancing economic feasibility with environmental goals.

In addition, integration challenges span regulatory uncertainty, high costs, and technical risks like induced seismicity. Environmental concerns include CO2 leakage risks, potential groundwater contamination, and ecological effects. Long-term monitoring through seismic, geochemical, and satellite technologies ensures safety and containment. Addressing these interdisciplinary issues is also vital for advancing carbon management solutions and achieving global climate targets.

This Special Issue welcomes research articles in the following areas:

CO2 Sequestration: Techniques, mechanisms (e.g., structural trapping), or case studies (e.g., Sleipner in the North Sea, Illinois Basin in the U.S.).

Plume Propagation: Modeling, monitoring, and examples of successful subsurface tracking.

CO2 EOR: Case studies, operational challenges, or integration with sequestration.

Integration Challenges: Regulatory, economic, or technical barriers.

Environmental Impact: Leakage risks, long-term monitoring, or effects on local ecosystems.

Prof. Dr. Fathi Boukadi
Dr. Talal Gamadi
Prof. Dr. Abdulrazag Zekri
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. Processes is an international peer-reviewed open access monthly 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 2400 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

  • CO2 sequestration
  • plume propagation
  • CO2 EOR
  • integration challenges
  • environmental impact

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Published Papers (3 papers)

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Research

15 pages, 3524 KiB  
Article
A Generalized Model for Estimating the Viscosity of Crude Oil
by Xiaodong Gao, Tianwen Jiang and Yang Li
Processes 2025, 13(5), 1433; https://doi.org/10.3390/pr13051433 - 8 May 2025
Viewed by 348
Abstract
Currently, most crude oil viscosity correlations rely only on API gravity and temperature, resulting in significant limitations in accurately predicting crude oil viscosity. To address this issue, this paper systematically explores the effect of API gravity, and crude oil components (saturates, aromatics, resins, [...] Read more.
Currently, most crude oil viscosity correlations rely only on API gravity and temperature, resulting in significant limitations in accurately predicting crude oil viscosity. To address this issue, this paper systematically explores the effect of API gravity, and crude oil components (saturates, aromatics, resins, and asphaltenes content), on viscosity based on 251 crude oil samples through sensitivity analysis. To overcome the shortcoming of traditional models, this paper proposes an innovative generalized viscosity model that combines the Levenberg–Marquardt (LM) and universal global optimization (UGO) methods to fully consider the effects of API gravity and various crude oil components. To verify the effectiveness of the model, this paper divides the 251 crude oil samples into a training set (202 samples) and a test set (49 samples) and compares the prediction results of the new model with the traditional. The results show that the prediction accuracy of the new model on the training set and test set is significantly better than that of the traditional model, with the minimum average absolute relative deviation reaching 10.13% and 12.4%, respectively. This study not only improves the accuracy of crude oil viscosity prediction but also provides early warning of increased pipeline friction caused by abnormal viscosity, avoids suspension accidents, and ensures the safe operation of long-distance pipelines. Full article
(This article belongs to the Special Issue Advances in Oil and Gas Reservoir Modeling and Simulation)
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18 pages, 5633 KiB  
Article
Analysis of Enhanced Geothermal System Reservoir Parameters and Fractures on Heat Recovery Efficiency Based on a Single-Phase Conduction Model
by Yuting Luo, Juyan Wei, Meilong Fu, Li Fang and Xudong Li
Processes 2025, 13(4), 1135; https://doi.org/10.3390/pr13041135 - 9 Apr 2025
Viewed by 385
Abstract
Geothermal energy has the advantages of being green, stable, abundant, and renewable. The thermal energy extraction efficiency of an enhanced geothermal system (EGS) is significantly regulated by Thermo–Hydraulic (TH) processes. To accurately evaluate the long-term heat recovery performance of an EGS, the dynamic [...] Read more.
Geothermal energy has the advantages of being green, stable, abundant, and renewable. The thermal energy extraction efficiency of an enhanced geothermal system (EGS) is significantly regulated by Thermo–Hydraulic (TH) processes. To accurately evaluate the long-term heat recovery performance of an EGS, the dynamic influence mechanisms under multi-field TH coupling effects must be considered comprehensively. Therefore, in this study, based on the local thermal equilibrium theory, a temperature–seepage coupling model is established using the COMSOL software. The influences of reservoir parameters and fractures on the geothermal energy mining effect are studied, and the distribution law of temperature and pressure in the thermal reservoir is analyzed. The research results provide a reference for EGS reservoir reconstruction and heat recovery efficiency optimization. It is shown that the temperature difference near the injection–production well in the early stage of development leads to the slow recovery of thermal reservoir pressure. When the matrix permeability is greater than 455 mD, the temperature of the production fluid drops too quickly, and the development life of the thermal reservoir is short. The matrix porosity has little effect on the development of thermal reservoirs. When the porosity increases from 0.05 to 0.3, after 40 years of production, the mass flow rate of the produced fluid increases by 3.08%, the temperature of the produced fluid increases by 2.14%, and the heat recovery rate increases by 7.04%. The number of fractures has a significant influence on the development of thermal reservoirs. When the number of fractures increases from 0 to 3, the mass flow rate of production fluid increases by 55.9%, the thermal breakthrough is rapid, and the development life of the thermal reservoir is shortened. Notably, the unreasonable use of cracks will hinder the outward spread of the injected fluid. Full article
(This article belongs to the Special Issue Advances in Oil and Gas Reservoir Modeling and Simulation)
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15 pages, 12350 KiB  
Article
Optimizing Oil Recovery: A Sector Model Study of CO₂-Water-Alternating-Gas and Continuous Injection Technologies
by Majid Hussain, Fathi Boukadi, Zeming Hu and Derrick Adjei
Processes 2025, 13(3), 700; https://doi.org/10.3390/pr13030700 - 28 Feb 2025
Viewed by 841
Abstract
Optimizing oil recovery from mature reservoirs remains a key challenge in the petroleum industry. This study evaluates the efficiency of CO2-WAG injection compared to continuous CO2 and water flooding using a sector model of the X Oil Field. A [...] Read more.
Optimizing oil recovery from mature reservoirs remains a key challenge in the petroleum industry. This study evaluates the efficiency of CO2-WAG injection compared to continuous CO2 and water flooding using a sector model of the X Oil Field. A compositional reservoir simulator was employed to analyze oil recovery under water-wet and mixed-wet conditions, incorporating three-phase relative permeability and wettability effects. The results show that continuous CO2 flooding yields the highest oil recovery, with water-wet systems outperforming mixed-wet reservoirs. CO2-WAG injection provides a balanced approach, enhancing recovery while enabling CO2 sequestration, but remains less effective than continuous CO2 flooding. Water flooding, though the least efficient in terms of oil recovery, demonstrates long-term production stability. The gas–oil ratio (GOR) is notably higher in CO2-WAG, indicating gas breakthrough challenges. These findings emphasize the significant role of wettability in enhanced oil recovery (EOR) and suggest that continuous CO2 flooding is the most effective technique for maximizing production in heterogeneous reservoirs. This study contributes valuable insights for optimizing injection strategies, improving hydrocarbon recovery, and supporting sustainable reservoir management. Full article
(This article belongs to the Special Issue Advances in Oil and Gas Reservoir Modeling and Simulation)
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