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Exploitation of Geological Resources in Unconventional Reservoirs
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Exploitation of Geological Resources in Unconventional Reservoirs

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

Deadline for manuscript submissions: closed (7 April 2023) | Viewed by 15221

Special Issue Editors

Dr. Xia Yan

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: coupled multiphase flow and geomechanics in fractured porous media; numerical simulation in unconventional reservoirs
Dr. Qi Zhang

E-Mail Website
Guest Editor
Department of Civil and Environmental Engineering, The Hong Kong Polytechnic University, Kowloon 999077, Hong Kong
Interests: double porosity media; poroelasticity; transverse isotropy; mixture theory
Dr. Lijun Liu

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: fluid injection-induced fault reactivation and seismicity; coupled flow and geomechanics; numerical simulation; hydraulic fracturing diagnostic
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

With the increase in energy demand and the exhaustion in conventional resources, unconventional resources (e.g., shale gas, shale oil, coalbed methane, gas hydrate, and geothermal resources) have recently drawn great attention worldwide. Compared to conventional reservoirs, unconventional reservoirs have special pore structure characteristics and geological conditions, which make it challenging to characterize the fluid flow and explore geological resources using traditional approaches. Therefore, new methods, such as multistage fracturing with horizontal wells, in situ conversion, and enhanced geothermal systems, are being continuously developed and successfully applied for the exploitation of geological resources in unconventional reservoirs.

This Special Issue aims to present and disseminate recent advances about the exploitation of geological resources in unconventional reservoirs. Original contributions including experimental studies, numerical simulation, and theoretical analysis are expected. Topics of interest for publication include but are not limited to:

  • Reservoir characterization and modeling;
  • Geomechanics for unconventional reservoirs;
  • Multiphase fluid flow in unconventional reservoirs;
  • Pore-scale and reservoir scale simulation studies;
  • Machine learning applications in exploration of unconventional resources;
  • Geothermal energy extraction;
  • In situ conversion technology;
  • Hydraulic fracturing;
  • Production optimization;
  • CO2 sequestration and enhanced oil recovery.

Dr. Xia Yan
Dr. Qi Zhang
Dr. Lijun Liu
Guest Editors

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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 resources
  • shale oil and gas
  • tight oil and gas
  • coal bed methane
  • gas hydrates
  • geothermal resources
  • fractured karst reservoir
  • CO2 sequestration

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Published Papers (7 papers)

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Research

25 pages, 14292 KiB  
Article
Prospect Evaluation of the Cretaceous Yageliemu Clastic Reservoir Based on Geophysical Log Data: A Case Study from the Yakela Gas Condensate Field, Tarim Basin, China
by Wakeel Hussain, Muhsan Ehsan, Lin Pan, Xiao Wang, Muhammad Ali, Shahab Ud Din, Hadi Hussain, Ali Jawad, Shuyang Chen, Honggang Liang and Lixia Liang
Energies 2023, 16(6), 2721; https://doi.org/10.3390/en16062721 - 14 Mar 2023
Cited by 19 | Viewed by 2506
Abstract
This paper evaluated the oil and gas potential of the Cretaceous Yageliemu clastic reservoir within the Yakela condensed gas field lying in the Kuqa Depression, Tarim Basin, China. The petrophysical properties of the interest zones in the Kuqa area were characterized using geophysical [...] Read more.
This paper evaluated the oil and gas potential of the Cretaceous Yageliemu clastic reservoir within the Yakela condensed gas field lying in the Kuqa Depression, Tarim Basin, China. The petrophysical properties of the interest zones in the Kuqa area were characterized using geophysical logs from five wells. The results reveal that the gas-bearing zones are characterized by high resistivity, good permeability (K) and effective porosity (Φeff), low water saturation (Sw), and low shale concentration (Vsh), reflecting clean sand. The shale distribution model showed that these shales have no major influence on porosity and fluid saturation. The average shale volume, average effective porosity, and hydrocarbon saturation indicate that the Cretaceous Yageliemu Formation in the studied area contains prospective reservoir properties. The spatial distribution of petrophysical parameters, reservoir rock typing (RRT), and lithofacies were analyzed using the cross plots of litho saturation (volumetric analysis), iso-parametric representations of the petrophysical characteristics, cluster analysis, and self-organizing feature maps, respectively. The southeastern and northeastern regions of the research area should be ignored because of their high water and shale concentrations. The sediments in the southwest and northwest include the most potential reservoir intervals that should be considered for the future exploration and development of oil and gas fields in the study area. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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15 pages, 5978 KiB  
Article
Pore-Scale Simulation of Gas and Water Two-Phase Flow in Rough-Walled Fractures Using the Volume of Fluid Method
by Qingzhong Zhu, Yanhui Yang, Xueying Zhang, Sanshuai Wang, Jinzhao Yang and Jiyuan Zhang
Energies 2022, 15(24), 9382; https://doi.org/10.3390/en15249382 - 11 Dec 2022
Cited by 1 | Viewed by 1820
Abstract
The gas and water flow behavior in rough-walled hydrophilic fractures at the pore scale is crucial for understanding the gas production characteristics of naturally fractured formations. This paper presents a systematic analysis of the gas and water flow characteristics in both the single-fracture [...] Read more.
The gas and water flow behavior in rough-walled hydrophilic fractures at the pore scale is crucial for understanding the gas production characteristics of naturally fractured formations. This paper presents a systematic analysis of the gas and water flow characteristics in both the single-fracture and Y-shaped junction fracture models using the volume of fluid (VOF) method. Numerical simulations showed that the gas/water rate ratio is the most significant factor influencing gas bubble/slug geometry, phase distribution, and saturation. The effect of fracture roughness and tortuosity is less significant than the gas/water ratio, whereas the total fluid rate has a negligible effect. For Y-shaped junction models, the phase distribution and referential pathways are predominantly controlled only by the channel aperture ratio, whereas the effect of the intersecting angle and fluid flow rate can be neglected. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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16 pages, 6825 KiB  
Article
Characteristics and Seismic Identification Mode of Ultra-Deep Carbonate Fault-Controlled Reservoir in Northwest China
by Wei Gong, Xiaotao Wen and Dongyong Zhou
Energies 2022, 15(22), 8598; https://doi.org/10.3390/en15228598 - 17 Nov 2022
Cited by 8 | Viewed by 2279
Abstract
Ordovician carbonate reservoirs in the Shunbei area of the Tarim Basin are characterized by large burial depth, small vertical fault displacement of the strike-slip fault zone, small karst development scale, strong reservoir heterogeneity, complex and diverse seismic reflection types, which lead to unclear [...] Read more.
Ordovician carbonate reservoirs in the Shunbei area of the Tarim Basin are characterized by large burial depth, small vertical fault displacement of the strike-slip fault zone, small karst development scale, strong reservoir heterogeneity, complex and diverse seismic reflection types, which lead to unclear seismic response characteristics of fault zone and reservoir, and further restrict the fine description of ultra-deep (>7300 m) fault controlled reservoirs. On the basis of high-precision 3D seismic data analysis, combined with drilling, logging, and comprehensive geological interpretation data in the Shunbei area, seismic geological models of different types of reservoirs and fault zones are established. The changes in seismic response characteristics of fault zones and reservoirs are simulated and analyzed by changing reservoir size, scale, fault and fracture cavity combination modes, as well as other factors. On this basis, two seismic identification models of fault-controlled reservoirs in the Shunbei area are summarized and established. The seismic identification mode of seismic reflection marker wave of fault-controlled reservoir is mainly “fault seismic response characteristics & weak reflection” and red trough anomaly under T74. The internal seismic identification modes are mainly “fault seismic response characteristics & random reflection”, “fault seismic response characteristics & beading”, “fault seismic response characteristics & linear weak reflection”, and “fault seismic response characteristics & random reflection”. Among them, except for “fault seismic response characteristics & random reflection”, the coincidence rate of reservoir prediction of other three types of seismic response characteristics is more than 70%. The coincidence rate of the other three types of seismic response characteristics of a reservoir is more than 70%. The research results provide a reference for the prediction and description of ultra-deep carbonate fault-controlled reservoirs. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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17 pages, 5258 KiB  
Article
Reservoir Characteristics and Controlling Factors of Sedimentary Pyroclastic Rocks in Deep-Buried Basins: A Case Study of Yingtai Fault Depression, Southern Songliao Basin
by Ranlei Zhao, Xiao Xu, Wentao Ma, Cunlei Li, Qiushi Zhang and Qingyou Yue
Energies 2022, 15(18), 6594; https://doi.org/10.3390/en15186594 - 9 Sep 2022
Viewed by 2320
Abstract
In this article, based on core description, thin section, scanning electron microscope (SEM), well logging and reservoir physical properties, the reservoir controlling factors of sedimentary pyroclastic rocks in deep-buried basins are assessed via the relation between reservoirs and defining factors, including lithological characteristics, [...] Read more.
In this article, based on core description, thin section, scanning electron microscope (SEM), well logging and reservoir physical properties, the reservoir controlling factors of sedimentary pyroclastic rocks in deep-buried basins are assessed via the relation between reservoirs and defining factors, including lithological characteristics, sedimentary microfacies and diagenesis. In addition, the contributing factors of anomalously high-porosity and high-permeability zone are analyzed. The lithological characteristics and diagenesis of the sedimentary pyroclastic rocks are closely related to reservoirs. The reservoir porosity–permeability of sedimentary pyroclastic rocks with large volcanic clastic particles is better than in those with small volcanic clastic particles. Sedimentary pyroclastic rocks with high content of unstable clastic particles, such as feldspar and rock debris, are easier to form the high-quality reservoirs than those with high content of quartz. The dissolution is the most important and direct reason to form the anomalously high-porosity and high-permeability zones of the sedimentary pyroclastic rocks in deep-buried basins. It is concluded that the size and composition of the clastic particles in the sedimentary pyroclastic rocks are the internal-controlling factors of the effective reservoirs, while the diagenetic fluid and the burial process are the external-controlling factors which form the effective reservoirs. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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13 pages, 1928 KiB  
Article
Methane Hydrate Behavior for Water–Oil Systems Containing CTAB and Synperonic PE/F127 Surfactants
by Antonio Pavón-García, Abel Zúñiga-Moreno, Ricardo García-Morales, Hugo I. Pérez-López and Octavio Elizalde-Solis
Energies 2022, 15(14), 5213; https://doi.org/10.3390/en15145213 - 19 Jul 2022
Cited by 1 | Viewed by 1891
Abstract
Methane hydrates were studied in systems containing aqueous dissolved surfactants in oil emulsions with a volume ratio of 40/60. Two commercial surfactants, named synperonic PE/F127 and cetyltrimethylammonium bromide, were evaluated at 0, 350, 700 and 1500 ppm. Experiments were made by applying the [...] Read more.
Methane hydrates were studied in systems containing aqueous dissolved surfactants in oil emulsions with a volume ratio of 40/60. Two commercial surfactants, named synperonic PE/F127 and cetyltrimethylammonium bromide, were evaluated at 0, 350, 700 and 1500 ppm. Experiments were made by applying the cooling–heating path in an isochoric high-pressure cell at different initial pressures of 5.5, 8.0, 10.0 and 12.0 MPa. The obtained parameters were induction time, temperature onset, pressure drop, and dissociation conditions. The results revealed that the dissociation curve for methane in water-in-oil emulsions was not modified by the surfactants. The crystallization (onset) temperature was higher using synperonic PE/F127 in comparison with zero composition, while the opposite occurred with cetyltrimethylammonium bromide. Both surfactants induced a delaying effect on the induction time and a lesser pressure drop. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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17 pages, 4712 KiB  
Article
Optimization of Non-Uniform Perforation Parameters for Multi-Cluster Fracturing
by Qingdong Zeng, Wenzheng Liu and Jun Yao
Energies 2022, 15(14), 5099; https://doi.org/10.3390/en15145099 - 13 Jul 2022
Cited by 2 | Viewed by 1663
Abstract
Stress shadowing affects the simultaneous propagation of fractures from multiple perforation clusters. Employing uniform perforation parameters for all clusters cause the unbalanced growth of fractures, which arouses the demand of optimizing non-uniform perforation parameters. An optimization workflow combining a fracture propagation model and [...] Read more.
Stress shadowing affects the simultaneous propagation of fractures from multiple perforation clusters. Employing uniform perforation parameters for all clusters cause the unbalanced growth of fractures, which arouses the demand of optimizing non-uniform perforation parameters. An optimization workflow combining a fracture propagation model and the particle swarm optimization method (PSO) is proposed for multi-cluster fracturing in this study. The fracture model considers the coupling of rock deformation and fluid flow along the wellbore and fractures, and it is solved by using the Newton iteration method. The optimization is performed by taking the variance of multiple fracture lengths as fitness value function in the frame of the PSO method. Numerical results show that using the same spacings and perforation parameters for all clusters is detrimental to the balanced growth of multiple fractures. The variance of fracture lengths drops greatly through optimization of cluster spacings and perforation number/diameter. Properly increasing the spacing and perforation number/diameter for the middle clusters promotes the balanced growth of multiple fractures. This study provides an efficient optimization workflow for multi-cluster fracturing treatment in horizontal wells. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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15 pages, 2534 KiB  
Article
Twin Shear Unified Strength Solution of Shale Gas Reservoir Collapse Deformation in the Process of Shale Gas Exploitation
by Ying Cui, Zhan Qu, Liang Wang, Ping Wang and Jun Fang
Energies 2022, 15(13), 4691; https://doi.org/10.3390/en15134691 - 26 Jun 2022
Viewed by 1445
Abstract
The collapse deformation of shale has a significant influence on the exploitation process. Experimental analysis has indicated a correlation coefficient range from 0.9814 to 0.9981 and the established sample regression formula could be used to express the relationship between the dynamic elastic modulus [...] Read more.
The collapse deformation of shale has a significant influence on the exploitation process. Experimental analysis has indicated a correlation coefficient range from 0.9814 to 0.9981 and the established sample regression formula could be used to express the relationship between the dynamic elastic modulus and static elastic modulus of shale specimens. Based on the twin shear unified-strength theory, where coefficient b was considered to express the effect of intermediate principal stress, with the deduced regression formula, the unified solution of major principal strains describing a critical collapse of the shale shaft wall was derived. The results showed that the intermediate principal stress had a significant influence on the major principal strain, describing the critical collapse of the shale shaft wall. At the same depth, the critical collapse major principal strain increased with the increase in the b values. With the change in b value from 0 to 1, the calculated difference in critical collapse major principal strain with the same wellbore depth would change from 22.1% to 45.5%. With the change in b value from 0 to 1, the calculated difference in critical collapse major principal strain with the same wellbore temperature would change from 22.1% to 45.6%. The unified solution formula of the major principal strain, describing the critical collapse of the shale shaft wall expressed by the dynamic elastic modulus, could adjust the contribution of intermediate principal stress by changing the values of b, while considering the influence of temperature and confining pressure. The twin shear unified-strength solution of the shale gas reservoir collapse deformation could be used to effectively evaluate the shale gas reservoir stability during shale gas exploitation. Full article
(This article belongs to the Special Issue Exploitation of Geological Resources in Unconventional Reservoirs)
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