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Fluids
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Mechanisms of Shale/Tight Oil and Gas Transport in Nanopores
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Mechanisms of Shale/Tight Oil and Gas Transport in Nanopores

A special issue of Fluids (ISSN 2311-5521).

Deadline for manuscript submissions: closed (15 March 2022) | Viewed by 5777

Special Issue Editors

Dr. Jinze Xu

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Guest Editor
Department of Chemical & Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: shale gas; heavy oil; gas hydrate
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Zhangxing John Chen

E-Mail Website
Guest Editor
Department of Chemical & Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: carbon capture and storage (CCS); cyclic steam stimulation (CSS); steam-assisted gravity drainage (SAGD); expanding solvent steam-assisted gravity drainage (ES-SAGD); vapor extraction process (VAPEX) for heavy oil and bitumen reservoirs; hydraulic fracturing for shale, tight oil and gas, and CBM (coal bed methane); underground coal gasification (UCG).
Special Issues, Collections and Topics in MDPI journals
Dr. Xiaohu Dong

E-Mail Website
Guest Editor
College of Petroleum Engineering, China University of Petroleum, Beijing 102249, China
Interests: thermal recovery; EOR; unconventional resources; reservoir engineering; reservoir simulation
Prof. Dr. Keliu Wu

E-Mail Website
Guest Editor
College of Petroleum Engineering, China University of Petroleum-Beljing, Beijing 102249, China
Interests: shale; nanopores; fluid transport; phase behavior; CCUS
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

As important geofluid resources, shale/tight oil and gas have been game changers in the worldwide energy revolution. With advances in the technology of hydraulic fracturing and horizontal wells, key progress has been made in the development of shale/tight oil and gas reservoirs in North America and Asia. However, there are still many challenges when it come to the prediction of production, and in particular, the mechanism of shale/tight oil and gas transport in nanopores still needs further investigation.

The existence of shale/tight nanopores makes the pore size distribution complex and increases the heterogeneity of transport pathways. As many flow regimes exist, classical Darcy’s law is not able to describe the transport behavior of oil and gas in shale/tight sandstone nanopores. The confinement of nanopores also makes the phase behavior different from conventional reservoirs. Thus, many modelling and experimental studies have been performed in the past to deal with the challenges. This Special Issue aims to cover the most recent advances in the understanding of shale/tight oil and gas transport in nanopores. We encourage submissions focusing on modelling and experimental studies to address the challenge of the nano-scale transport process in shale/tight rocks. Both original research and review articles are welcomed.

Potential topics include, but are not limited to, the following:

  1. Phase behavior description in nanopores
  2. Numerical/analytical models for oil/gas transport in shale/tight sandstone nanopores
  3. Experimental/modelling study of imbibition
  4. Pore-scale modelling and simulation
  5. Nanoscale geomechanical research in shale/tight rocks
  6. Water-rock interaction in shale/tight sandstone nanopores
  7. Multiphase relative permeability curves in shale/tight sandstone nanopores.

Dr. Jinze Xu
Prof. Dr. Zhangxing John Chen
Dr. Xiaohu Dong
Dr. Keliu Wu
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. Fluids 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 1800 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.

Published Papers (2 papers)

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Research

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31 pages, 489 KiB  
Article
Development of a Scalable Thermal Reservoir Simulator on Distributed-Memory Parallel Computers
by Hui Liu, Zhangxin Chen, Xiaohu Guo and Lihua Shen
Fluids 2021, 6(11), 395; https://doi.org/10.3390/fluids6110395 - 2 Nov 2021
Cited by 3 | Viewed by 1952
Abstract
Reservoir simulation is to solve a set of fluid flow equations through porous media, which are partial differential equations from the petroleum engineering industry and described by Darcy’s law. This paper introduces the model, numerical methods, algorithms and parallel implementation of a thermal [...] Read more.
Reservoir simulation is to solve a set of fluid flow equations through porous media, which are partial differential equations from the petroleum engineering industry and described by Darcy’s law. This paper introduces the model, numerical methods, algorithms and parallel implementation of a thermal reservoir simulator that is designed for numerical simulations of a thermal reservoir with multiple components in three-dimensional domain using distributed-memory parallel computers. Its full mathematical model is introduced with correlations for important properties and well modeling. Efficient numerical methods (discretization scheme, matrix decoupling methods, and preconditioners), parallel computing technologies, and implementation details are presented. The numerical methods applied in this paper are suitable for large-scale thermal reservoir simulations with dozens of thousands of CPU cores (MPI processes), which are efficient and scalable. The simulator is designed for giant models with billions or even trillions of grid blocks using hundreds of thousands of CPUs, which is our main focus. The validation part is compared with CMG STARS, which is one of the most popular and mature commercial thermal simulators. Numerical experiments show that our results match commercial simulators, which confirms the correctness of our methods and implementations. SAGD simulation with 7406 well pairs is also presented to study the effectiveness of our numerical methods. Scalability testings demonstrate that our simulator can handle giant models with billions of grid blocks using 100,800 CPU cores and the simulator has good scalability. Full article
(This article belongs to the Special Issue Mechanisms of Shale/Tight Oil and Gas Transport in Nanopores)
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Review

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30 pages, 33349 KiB  
Review
Foam Based Fracturing Fluid Characterization for an Optimized Application in HPHT Reservoir Conditions
by Maria E. Gonzalez Perdomo and Sharifah Wan Madihi
Fluids 2022, 7(5), 156; https://doi.org/10.3390/fluids7050156 - 28 Apr 2022
Cited by 3 | Viewed by 3028
Abstract
Water-based fracturing fluids are among the most common fluid types used in hydraulic fracturing operations. However, these fluids tend to cause damage in water-sensitive formations. Foam comprises a small amount of base fluid, and compressible gas such as carbon dioxide and nitrogen has [...] Read more.
Water-based fracturing fluids are among the most common fluid types used in hydraulic fracturing operations. However, these fluids tend to cause damage in water-sensitive formations. Foam comprises a small amount of base fluid, and compressible gas such as carbon dioxide and nitrogen has emerged as a more ecologically friendly option to fracture such formations. Foam is an attractive option since it has a low density and high viscosity. The applicability of foamed frac fluid is characterized by foam stability and rheology, encompassing the viscosity and proppant carrying ability. The foam quality, pressure and temperature affect the foam rheology. Generally, foam viscosity and stability increase with pressure but decrease when the temperature increases. Hence, it is essential to preserve foam stability in high pressure and high temperature (HPHT) reservoir conditions. The addition of nanoparticles could increase the thermal stability of the foam. This article provides the basis of foam-based fracturing fluid characterization for an optimal application in HPHT reservoir conditions. Then, focusing on improving thermal stability, it reviews the research progress on the use of nanoparticles as foam stabilizing agent. This paper also sheds light on the literature gaps that should be addressed by future research. Full article
(This article belongs to the Special Issue Mechanisms of Shale/Tight Oil and Gas Transport in Nanopores)
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