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Oil and Gas Reservoir Stimulation Theory and Technology

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

Deadline for manuscript submissions: closed (28 June 2023) | Viewed by 5100

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Special Issue Editor

Dr. Zhengbin Wu

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Guest Editor

School of Energy Resources, China University of Geosciences, Wuhan 430074, China
Interests: tight/shale oil; CO₂; molecular dynamics; fracturing; numerical simulation; EOR
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Given the continuous increase in global energy demand and the many uncertainties of energy supply ahead, unconventional resources will continue to play a crucial role during the energy transition process. One should pay special attention not only to the stability and availability of unconventional resources, but also to the development of transformational technologies for unconventional resources systems that will contribute to oil and gas development.

Considering all the above, we are pleased to propose a Special Issue with the title of “Oil and Gas Reservoir Stimulation Theory and Technology”. This Special Issue will primarily cover oil and gas extraction (e.g., tight/shale oil and gas), while highlighting theoretical, technological, and practical development and improvement in the literature of these areas. We welcome manuscripts at subnational, national, or international levels, as well as those from legal, ethical, and social aspects. No methodology constraints will be applied. Innovative technologies and methods are especially encouraged.

Suitable topics include but are not limited to the following:

Tight/shale oil exploration and development;
Tight/shale gas exploration and development;
Oil shale exploitation;
CO₂ enhanced oil/gas technologies;
Underground coal gasification;
Numerical simulation for oil and gas;
Underground fluid flow modeling in porous media;
Some other related topics in unconventional resources engineering.

Dr. Zhengbin Wu
Guest Editor

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

tight/shale oil
tight/shale gas
CO₂
numerical simulation
fluid flow modeling
molecular dynamics
machine learning

Published Papers (3 papers)

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Research

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22 pages, 23011 KiB

Open AccessArticle

Integrated Geomodel Accuracy Enhancement Based on Embedded MPS Geological Modeling for Thin Interbedded Reservoirs

by Ling Ke, Fengming Ruan, Taizhong Duan, Zhiping Li, Xiangzeng Wang and Lei Zhao

Energies 2023, 16(19), 6850; https://doi.org/10.3390/en16196850 - 27 Sep 2023

Viewed by 777

Abstract

Continental delta deposits are characterized by strong heterogeneity in the lateral direction; meanwhile, reservoir development is challenged by rapid changes in rock properties. Thus, it is critical to use proper methods for fine characterization to confirm the distributions of thin interbedded reservoirs. The aim of this study was to propose a novel workflow for integrated research on the 3D geomodeling of thin interbedded reservoirs, using the Triassic T₂a¹ formation in the Tahe Oilfield B9 area of the Tarim Basin as a case study. The complicated representation of thin interbeds in a 3D geomodel was simulated using a multiscale joint controlling strategy, based on wells (Points), 2D geological cross-sections (Lines), and horizontal wells (Surfaces). The resistivity inversion results from the horizontal wells validated the proof of the plane distribution of the thin interbeds within the drilled area, and this quantitative statistic provided effective parameters and guidance for 3D interbed geomodeling. In this study, comprehensive 3D facies modeling was divided into 3D interbed geomodeling and 3D sedimentary facies modeling. An optimized interbed geomodel was picked out from multiple stochastic simulation realizations, and the drilled horizontal well data were used to constrain the simulation process, so the simulation results were more consistent with the real distribution of the thin interbed morphology. Classical two-point geostatistical methods, the multipoint simulation (MPS) geostatistical method, and the hierarchical mindset were integrated for the microfacies simulation. This procedure demonstrated a good ability to characterize thin interbed reservoirs in continental delta deposits. An MPS training image obtained from a high-resolution satellite photo was used to fix the issue of the relationships between the distributions and configurations of all microfacies within the spatial distribution. A 3D lithofacies interbed model was embedded into the 3D facies model. This comprehensive facies model served as a constraint condition in the property modeling process. A porosity model was simulated using separate stratigraphy and individual microfacies controls, as facies-controlled property modeling has been used as a prior foundation for field development planning in the Tahe Oilfield B9 case. The porosity model was then used as a basis for permeability modeling, and a water saturation model was created using the J function and all of the constraints from the other two property models. Finally, all the results were validated using dynamic production data from the Tahe Oilfield B9 wells, with good matching observed between the geological models. There was only a 0.92% difference in reservoir volume between the reservoir simulation results and the static geological model results using our solution. Full article

(This article belongs to the Special Issue Oil and Gas Reservoir Stimulation Theory and Technology)

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19 pages, 8506 KiB

Open AccessArticle

Numerical Simulation of the Oil Production Performance of Different Well Patterns with Water Injection

by Elia Wilinasi Sikanyika, Zhengbin Wu, Mbarouk Shaame Mbarouk, Adamu Musa Mafimba, Husham Ali Elbaloula and Shu Jiang

Energies 2023, 16(1), 91; https://doi.org/10.3390/en16010091 - 21 Dec 2022

Cited by 2 | Viewed by 2255

Abstract

Numerical reservoir simulation, which includes the construction and operation of a model that performs similarly to a real-world reservoir, is an effective method for exploring complex reservoir issues. Due to the complexity of constructing reservoir environments for experiments, numerical simulation is a vital method for studying flow behavior under reservoir conditions. In this study, a black-oil modeling simulator was used to construct, simulate, and evaluate a conceptual hydrocarbon reservoir model. The model evolved by drilling two production wells and one injection well in two cases. The first case consisted of two horizontal production wells and one injection well, while the second consisted of two vertical production wells and an injection well. In total, 25 simulation runs were performed, and the results showed that horizontal wells perform better than vertical wells in terms of productivity, with a field oil production total of 1,930,000 m³. This is significantly higher than vertical wells, which have a field oil production total of 1,890,000 m³ after 1840 days. The field recovery factor for horizontal wells was 41% and for vertical wells it was 39%, both of which were less than 50%. This indicates that the reservoir’s sweeping efficiency was minimal. To enhance sweeping efficiency, the water injection rate and number of injection wells should be increased, as well as well patterns and locations remodeled. It was also shown that as reservoir thickness increased, horizontal and vertical well productivity increased. In order to boost horizontal well productivity and increase field oil recovery above 50%, the horizontal well length should be increased to take up a wider area of the reservoir portion. On the other hand, well length may have no impact on vertical well production efficiency. Full article

(This article belongs to the Special Issue Oil and Gas Reservoir Stimulation Theory and Technology)

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Review

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29 pages, 3949 KiB

Open AccessReview

Current Status and Future Trends of In Situ Catalytic Upgrading of Extra Heavy Oil

by Zhengbin Wu, Hanzhao Chen, Xidong Cai, Qiyang Gou, Liangliang Jiang, Kai Chen, Zhangxin Chen and Shu Jiang

Energies 2023, 16(12), 4610; https://doi.org/10.3390/en16124610 - 9 Jun 2023

Cited by 5 | Viewed by 1664

Abstract

In situ catalytic upgrading of heavy oil decomposes viscous heavy oil underground through a series of complex chemical and physical reactions with the aid of an injected catalyst, and permits the resulting lighter components to flow to the producer under a normal pressure drive. By eliminating or substantially reducing the use of steam, which is prevalently used in current heavy oil productions worldwide and is a potent source of contamination concerns if not treated properly, in situ catalytic upgrading is intrinsically environmental-friendly and widely regarded as one of the promising techniques routes to decarbonize the oil industry. The present review provides a state-of-the-art summarization of the technologies of in situ catalytic upgrading and viscosity reduction in heavy oil from the aspects of catalyst selections, catalytic mechanisms, catalytic methods, and applications. The various types of widely used catalysts are compared and discussed in detail. Factors that impact the efficacy of the in situ upgrading of heavy oil are presented. The challenges and recommendations for future development are also furnished. This in-depth review is intended to give a well-rounded introduction to critical aspects on which the in situ catalytic application can shed light in the development of the world’s extra heavy oil reservoirs. Full article

(This article belongs to the Special Issue Oil and Gas Reservoir Stimulation Theory and Technology)

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