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Flow in Porous Media and CO2 Storage in Enhanced...
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Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery

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

Deadline for manuscript submissions: 15 December 2024 | Viewed by 4507

Special Issue Editors

Dr. Qichao Lv

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Guest Editor
Unconventional Petroleum Research Institute, China University of Petroleum, Beijing 102249, China
Interests: CO2 sequestration;CO2 EOR; CO2 fracturing; CO2 mobility control; CO2 foam fluids
Dr. Abdolhossein Hemmati-Sarapardeh

E-Mail Website
Guest Editor
Department of Petroleum Engineering, Shahid Bahonar University of Kerman, Kerman 7616913439, Iran
Interests: CCUS; modeling; neural network; deep learning
Prof. Dr. Zihao Yang

E-Mail Website
Guest Editor
Unconventional Petroleum Research Institute, China University of Petroleum, Beijing 102249, China
Interests: enhanced oil recovery; chemical engineering and technology; colloid and interface chemistry; carbon dioxide flooding and storage
Dr. Boxin Ding

E-Mail Website
Guest Editor
Shenzhen Graduate School, School of Advanced Materials, Peking University, Shenzhen 518055, China
Interests: complex fluids (emulsions, foams, nanofluids, etc.); interface symptoms; multiphase seepage; mass and heat transfer; multi-scale numerical simulation

Special Issue Information

Dear Colleagues,

Climate change is a major global challenge critical to the development of the world. Carbon capture, utilization, and storage (CCUS) is considered to be a crucial method to reduce CO2 emission. As one of the most attractive technologies of CCUS, CO2-Enhanced oil recovery (CO2-EOR) has been employed to achieve CO2 geological storage and improve the production of crude oil. This technology brings economic benefits and shows great potential to tackle climate change.  

This Special Issue on “Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery” aims to cover recent advances in the theory and application of CO2 Sequestration, CO2 flooding, CO2 huff-puff, CO2 fracturing, and other related topics. Novel experimental and numerical research, reviews of recent developments, and emerging technologies about the topic are welcome.

Dr. Qichao Lv
Dr. Abdolhossein Hemmati-Sarapardeh
Prof. Dr. Zihao Yang
Dr. Boxin Ding
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 storage
  •  EOR
  •  porous media
  •  flooding
  •  mobility control
  •  miscibility
  •  huff-puff
  •  fracturing

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Published Papers (4 papers)

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Research

13 pages, 6493 KiB  
Article
Property Changes of Low-Permeability Oil Reservoirs Under Long-Term Water Flooding
by Lili Lin, Chongjun Xu, Haifeng Lyu, Yuping Chen, Shuping Cong, Xingxing Yang and Wengang Bu
Processes 2024, 12(11), 2317; https://doi.org/10.3390/pr12112317 - 23 Oct 2024
Viewed by 587
Abstract
The property changes of low-permeability oil reservoirs after long-term water flooding remain insufficiently understood. This study conducted water flooding experiments on three real core samples and employed scanning electron microscopy (SEM), X-ray diffraction (XRD), and nuclear magnetic resonance (NMR) to analyze how the [...] Read more.
The property changes of low-permeability oil reservoirs after long-term water flooding remain insufficiently understood. This study conducted water flooding experiments on three real core samples and employed scanning electron microscopy (SEM), X-ray diffraction (XRD), and nuclear magnetic resonance (NMR) to analyze how the changes in mineral and pore structure relate to permeability changes before and after water flooding. The results showed that the core permeability decreased significantly after water flooding, with a decrease rate of 69.7%, 19.6%, and 34.4% for the three cores. The well test results of the block also indicate that the reservoir permeability decreases after long-term water injection, with an average decrease of over 60%. The clay mineral content decreased notably, with the largest decrease of 8.6 percentage points in kaolinite and minor decreases in chlorite and illite. SEM results also indicated erosion and damage to the clay mineral structure by the water flow, and kaolinite has a high degree of dissolution. The NMR results showed that after water flooding, the pore size curve shifted to the left, the relaxation time decreased, the number of small pores in the cores increased, and the number of large pores decreased. The median pore radius decreased by 3.4% to 21.53%. Full article
(This article belongs to the Special Issue Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery)
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19 pages, 10528 KiB  
Article
Research on Water Invasion Law and Control Measures for Ultradeep, Fractured, and Low-Porosity Sandstone Gas Reservoirs: A Case Study of Kelasu Gas Reservoirs in Tarim Basin
by Dong Chen, Chengze Zhang, Min Yang, Haiming Li, Cuili Wang, Pengxiang Diwu, Hanqiao Jiang and Yong Wang
Processes 2024, 12(2), 310; https://doi.org/10.3390/pr12020310 - 1 Feb 2024
Cited by 2 | Viewed by 966
Abstract
The exploitation of ultradeep, fractured, and low-porosity gas reservoirs often encounters challenges from water invasion, exacerbated by the presence of faults and fractures. This is particularly evident in the Kelasu gas reservoir group, located in the Kuqa Depression of the Tarim Basin. The [...] Read more.
The exploitation of ultradeep, fractured, and low-porosity gas reservoirs often encounters challenges from water invasion, exacerbated by the presence of faults and fractures. This is particularly evident in the Kelasu gas reservoir group, located in the Kuqa Depression of the Tarim Basin. The complexity of the water invasion patterns in these reservoirs demands a thorough investigation to devise effective water control measures. To elucidate the water invasion patterns, a combined approach of large-scale physical modeling and discrete fracture numerical simulations was adopted. These models allowed for the identification and categorization of water invasion behaviors in various gas reservoirs. Furthermore, production dynamic analysis was utilized to tailor water control strategies to specific invasion patterns. The large-scale physical simulation experiment revealed that water invasion in gas reservoirs is primarily influenced by high-permeability channels (faults + fractures), and that the gas production rate serves as the key factor governing gas reservoir development. The range of gas extraction rates spans from 3% to 5%. As the gas extraction rate increases, the extraction intensity diminishes and the stable production duration shortens. On the basis of the changes in the water breakthrough time and water production rate, a 2% gas extraction rate is determined as the optimal rate for the model. The embedded discrete fracture numerical simulation model further supports the findings of the physical simulation experiments and demonstrates that ① this type of gas reservoir exhibits typical nonuniform water invasion patterns, controlled by structural location, faults, and degree of crack development; ② the water invasion patterns of gas reservoirs can be categorized into three types, these being explosive water flooding and channeling along faults, uniform intrusion along fractures, and combined intrusion along faults and fractures; ③ drawing from the characteristics of water invasion in various gas reservoirs, combined with production well dynamics and structural location, a five-character water control strategy of “prevention, control, drainage, adjustment, and plugging” is formulated, with the implementation of differentiated, one-well, one-policy governance. The study concludes that a proactive approach, prioritizing prevention, is crucial for managing water-free gas reservoirs. For water-bearing reservoirs, a combination of three-dimensional water plugging and drainage strategies is recommended. These insights have significant implications for extending the productive lifespan of gas reservoirs, enhancing recovery rates, and contributing to the economic and efficient development of ultradeep, fractured, and low-porosity gas reservoirs. Full article
(This article belongs to the Special Issue Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery)
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14 pages, 6967 KiB  
Article
Numerical Reservoir Simulation of Supercritical Multi-Source and Multi-Component Steam Injection for Offshore Heavy Oil Development
by Qiang Fu, Zhouyuan Zhu, Junjian Li, Hongmei Jiao, Shuoliang Wang, Huiyun Wen and Yongfei Liu
Processes 2024, 12(1), 216; https://doi.org/10.3390/pr12010216 - 18 Jan 2024
Viewed by 1164
Abstract
We present the workflow for numerical reservoir simulation of supercritical multi-source and multi-component steam injection for offshore heavy oil development. We have developed unique techniques in a commercial reservoir simulator to implement the thermal properties of supercritical multi-source and multi-component steam, the pyrolysis [...] Read more.
We present the workflow for numerical reservoir simulation of supercritical multi-source and multi-component steam injection for offshore heavy oil development. We have developed unique techniques in a commercial reservoir simulator to implement the thermal properties of supercritical multi-source and multi-component steam, the pyrolysis chemical reactions, the temperature-dependent relative permeability, and the process of partially dissolving the sandstone rock to enhance the matrix permeability in a commercial reservoir simulator. Simulations are conducted on the type pattern reservoir model, which represents one of the heavy oil fields in CNOOC’s Bohai Bay oil field. Simulation input parameters are calibrated based on laboratory experiments conducted for supercritical multi-source and multi-component steam injection. Simulation results have shown clear improvements in injecting supercritical multi-source and multi-component steam in offshore heavy oil reservoirs compared to the normal steam injection process using subcritical steam. This serves as a workflow for implementing a numerical simulation of the novel supercritical multi-source and multi-component steam injection recovery process. Full article
(This article belongs to the Special Issue Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery)
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17 pages, 9552 KiB  
Article
Study on the Countermeasures and Mechanism of Balanced Utilization in Multilayer Reservoirs at Ultra-High Water Cut Period
by Yong Wang, Hanqiao Jiang, Zhiqiang Wang, Pengxiang Diwu and Junjian Li
Processes 2023, 11(11), 3111; https://doi.org/10.3390/pr11113111 - 30 Oct 2023
Cited by 4 | Viewed by 1108
Abstract
After entering the ultra-high water cut stage of multilayer oil reservoirs, the remaining oil is highly dispersed. Due to the continuous development of general water injection, the generation of advantageous channels makes interlayer contradictions more prominent, and the differences in the utilization between [...] Read more.
After entering the ultra-high water cut stage of multilayer oil reservoirs, the remaining oil is highly dispersed. Due to the continuous development of general water injection, the generation of advantageous channels makes interlayer contradictions more prominent, and the differences in the utilization between different layers are even greater. After the water drive development of multilayer oil reservoirs enters the ultra-high water cut stage, the development effect deteriorates year by year. Layer restructuring is an effective method of improving the water injection development effect and increasing the degree of utilization. In essence, its goal is to achieve balanced utilization for multiple development layers to increase the degree of recovery. This article mainly employs physical simulation experiments combined with reservoir numerical simulation technology to jointly study the effects of different equilibrium production strategies in the ultra-high water cut period of multilayer oil reservoirs and their mechanism of action based on the remaining oil distribution field and streamline field. As a specific implementation, we use large-plate physical simulation to demonstrate the effectiveness of the rotational injection and production strategy, and to supplement the physical simulation experiment with a reservoir numerical simulation model, we analyze the mechanism of different balanced production strategies. The research results for the combination of physical simulation experiments and numerical simulation experiments show that the combined strategy of rotary injection and rotary production is the most effective method for use in multilayer and ultra-high water cut oil reservoirs. The displacement effect of the high-permeability layer is better, and the increase in the recovery degree is relatively large, while the displacement effect of the low-permeability layer is relatively weak. After conventional water drive oil recovery, the remaining oil mainly exists in the edge area of the research area. However, the use of three-dimensional well network injection wheel recovery changes the streamline field, produces the effect of fluid flow diversion, expands the water drive sweep coefficient, and improves the recovery rate. Chemical plugging can effectively replace water drive oil recovery and will become the main method for improving the recovery rate of such reservoirs in the lower part. Full article
(This article belongs to the Special Issue Flow in Porous Media and CO2 Storage in Enhanced Oil Recovery)
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