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Latest Research Progress for Nanotech for Oil and Gas

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

Deadline for manuscript submissions: closed (30 June 2019) | Viewed by 23139

Special Issue Editors

Department of Chemical & Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: nano-/micro-fluidics; gas stroage; water adsorption; simulation for unconventional reservoirs (e.g., shale gas and tight gas formations)
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).
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Special Issue Information

Dear Colleague,

Owing to horizontal drilling and hydraulic fracturing, unconventional oil/gas resources, including coal bed methane (CBM), tight oil/gas and shale oil/gas, have become an indispensable part of global energy. However, due to the existence of abundant nanopores in coal, tight sandstone and shale, the flow behavior and storage characteristics of these unconventional oil/gas resources are strongly affected by nano-confinement, and an accurate estimation and/or prediction of the unconventional resources still faces numerous challenges. Therefore, studies on nano-scale mechanisms of gas/liquid flow and phase behavior in these unconventional reservoirs will contribute to resource evaluation, reservoir productivity, production forecast and optimization.

In order to further the nano-scale research related to the development of unconventional oil/gas resources, this Special Issue, entitled “Nanotech for Oil and Gas”, is proposed for the international journal Energies, which is an SCIE journal with an impact factor of 2.262 (2016). This Special Issue covers original research and studies related to the above-mentioned topics, including, but not limited to, oil/gas phase behavior, oil/gas flow and transport mechanisms, gas adsorption/desorption, and oil/gas production forecast. Papers selected for this Special Issue are subject to a rigorous peer-review procedure with the aim of rapid and wide dissemination of research results, development and applications.

Welcome to submit your work to this Special Issue, and we are looking forward to receiving your outstanding research.

Dr. Jing Li
Dr. Jinze Xu
Prof. Dr. Zhangxing John Chen
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

  • Unconventional oil/gas reservoirs
  • Micro/nano-flow
  • Nano-confinement
  • Phase behavior
  • Adsorption/desorption
  • Imbibition
  • Fluid-solid coupling
  • Reservoir simulation

Published Papers (7 papers)

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Research

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21 pages, 4654 KiB  
Article
Why Coal Bed Methane (CBM) Production in Some Basins is Difficult
by Andrzej Olajossy and Jerzy Cieślik
Energies 2019, 12(15), 2918; https://doi.org/10.3390/en12152918 - 29 Jul 2019
Cited by 10 | Viewed by 2557
Abstract
The changes in the permeability of coal-bed reservoirs with methane, as associated with gas depletion, are the consequence of two opposing processes, namely geomechanical compaction that narrows down fractures, and matrix shrinkage, which, in turn, widens fractures. Many previous studies on the effects [...] Read more.
The changes in the permeability of coal-bed reservoirs with methane, as associated with gas depletion, are the consequence of two opposing processes, namely geomechanical compaction that narrows down fractures, and matrix shrinkage, which, in turn, widens fractures. Many previous studies on the effects of these processes have emphasised, albeit not always, the circumstances and conditions that led to a greater coal permeability, with a natural decrease in the pore pressure of methane during its production, and, in consequence, to an increase in the cumulative volume of this gas. However, in some coal basins, there are beds where the methane production has failed to reach the appropriate level, whether in economic or engineering terms. This paper identifies some reasons for the failed attempts at well exploration of gas from such coal beds. Specifically, it describes seven parameters to be considered in relation to CBM, including geomechanical parameters such as Young’s modulus, Poisson’s ratio, and the initial porosity, which define coal cleat compressibility, a very important parameter, and parameters related to methane desorption, i.e., desorption-induced volumetric strain, the Langmuir pressure, and the initial pressure of gas within the bed. In addition to cleat compressibility, there are other, equally important parameters, such as the rebound pressure and recovery pressure, which are defined by the following parameters in order of importance: Young’s modulus, desorption-induced volumetric strain, initial pressure of methane, the Langmuir pressure, and Poisson’s ratio. To assess the impact of these parameters on changes in permeability, we used the Cui-Bastin model. The simulation results were analysed to allow us to present our findings. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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21 pages, 3670 KiB  
Article
Development of Nanofluids for Perdurability in Viscosity Reduction of Extra-Heavy Oils
by Daniel Montes, Wendy Orozco, Esteban A. Taborda, Camilo A. Franco and Farid B. Cortés
Energies 2019, 12(6), 1068; https://doi.org/10.3390/en12061068 - 20 Mar 2019
Cited by 25 | Viewed by 3637
Abstract
The primary objective of this study is the development of nanofluids based on different diluent/dispersant ratios (DDR) for extra-heavy oil (EHO) viscosity reduction and its perdurability over time. Different diluents such as xylene, diesel, n-pentane, and n-heptane were evaluated for the [...] Read more.
The primary objective of this study is the development of nanofluids based on different diluent/dispersant ratios (DDR) for extra-heavy oil (EHO) viscosity reduction and its perdurability over time. Different diluents such as xylene, diesel, n-pentane, and n-heptane were evaluated for the formulation of the carrier fluid. Instability of asphaltenes was assessed for all diluents through colloidal instability index (CII) and Oliensis tests. Rheology measurements and hysteresis loop tests were performed using a rotational rheometer at 30 °C. The CII values for the alkanes type diluents were around 0.57, results that were corroborated with the Oliensis tests as asphaltenes precipitation was observed with the use of these diluents. This data was related to the viscosity reduction degree (VRD) reported for the different diluents. With the use of the alkanes, the VRD does not surpass the 60%, while with the use of xylene a VRD of approximately 85% was achieved. Dimethylformamide was used as a dispersant of the nanoparticles and had a similar VRD than that for xylene (87%). Subsequent experiments were performed varying the DDR (xylene/dimethylformamide) for different dosages up to 7 vol % determining that a DDR = 0.2 and a dosage of 5 vol % was appropriated for enhancing EHO VRD, obtaining a final value of 89%. Different SiO2 nanoparticles were evaluated in the viscosity reduction tests reporting the best results using 9 nm nanoparticles that were then included at 1000 mg·L−1 in the carrier fluid, increasing the VRD up to 4% and enhancing the perdurability based on the rheological hysteresis and the viscosity measurements for 30 days. Results showed a viscosity increase of 20 and 80% for the crude oil with the nanofluid and the carrier fluid after 30 days, respectively. The nanoparticles have a synergistic effect in the viscosity reduction and the inhibition of the viscoelastic network re-organization (perdurability) after treatment application which was also observed in the rheological modeling carried out with Cross and Carreau models as the reported characteristic relaxation time was increased almost a 20%. Moreover, the Vipulanandan rheological model denotes a higher maximum stress value reached by the EHO with the addition of nanofluids which is derived from the EHO internal structure rearrangement caused by the asphaltenes adsorption phenomenon. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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18 pages, 14326 KiB  
Article
Growth Mechanism of Siliceous Cement in Tight Sandstone and Its Influence on Reservoir Physical Properties
by Bo Jiu, Wenhui Huang, Jing Shi and Mingqian He
Energies 2018, 11(11), 3133; https://doi.org/10.3390/en11113133 - 13 Nov 2018
Cited by 5 | Viewed by 3582
Abstract
To investigate the effect of siliceous cementation on the densification of sandstone and the forming process of tight sandstone, based on cathodoluminescence, scanning electron microscopy and thin section analysis, the growth mechanism and characteristics of quartz particles in tight sandstone formations are explored. [...] Read more.
To investigate the effect of siliceous cementation on the densification of sandstone and the forming process of tight sandstone, based on cathodoluminescence, scanning electron microscopy and thin section analysis, the growth mechanism and characteristics of quartz particles in tight sandstone formations are explored. Meanwhile, combined with conventional core analysis and X-ray diffraction experiments, the factors affecting the crystallization of quartz particles, including the chlorite content, grain size and clay mineral, are analyzed, respectively. The entire siliceous cementation is divided into two processes. The first part is the process in which the weathered and rounded particles in the formation are restored to the hexagonal dipyramid crystal by siliceous cementation. The second part is the process of coaxial growth that the hexagonal dipyramid crystal continues to increase with the form of micro-quartz film. As siliceous cements continue to increase, the petrological characteristics of sandstones are constantly changing. The tight sandstone developed in the study area is composed of lithic sandstone and quartz lithic sandstone. Based on the analysis results, 2D and 3D evolution models are established for densification of two different lithic sandstones. When the content of siliceous cement in the study area is less than 17%, the porosity of tight sandstone increases with the increase of cement. When the content of cement is more than 17%, the porosity of tight sandstone is negatively correlated with the content of cement. When the cement content is greater than 10%, the reservoir permeability is negatively correlated with it. Furthermore, the particle size mainly affects the permeability of reservoir, and the particle size is negatively correlated with the permeability of tight sandstone. The most high-quality tight sandstone reservoir in the study area is in the first cementation stage when siliceous cements are distributed in porphyritic texture with the content of 10–15% and a grain size of 0.2–0.3 mm. In addition, the relatively high-quality reservoir is the one developing clay mineral film with a content of cementation about 5–12%. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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13 pages, 4929 KiB  
Article
Nuclear Magnetic Resonance Measurement of Oil and Water Distributions in Spontaneous Imbibition Process in Tight Oil Reservoirs
by Xiangrong Nie and Junbin Chen
Energies 2018, 11(11), 3114; https://doi.org/10.3390/en11113114 - 10 Nov 2018
Cited by 11 | Viewed by 3295
Abstract
Spontaneous imbibition of water into tight oil reservoirs is considered an effective way to improve tight oil recovery. We have combined testing techniques such as nuclear magnetic resonance, mercury injection capillary pressure, and magnetic resonance imaging to reveal the distribution characteristics of oil [...] Read more.
Spontaneous imbibition of water into tight oil reservoirs is considered an effective way to improve tight oil recovery. We have combined testing techniques such as nuclear magnetic resonance, mercury injection capillary pressure, and magnetic resonance imaging to reveal the distribution characteristics of oil and water during the spontaneous imbibition process of tight sandstone reservoir. The experimental results were used to describe the dynamic process of oil–water distribution at the microscopic scale. The water phase is absorbed into the core sample by micropores and mesopores under capillary forces that dry away the original oil phase into the hydraulically connected macropores. The oil phase entering the macropores will drive away the oil in place and expel the original oil from the macropores. The results of magnetic resonance imaging clearly show that the remaining oil accumulates in the central region of the core because a large amount of water is absorbed in the late stage of spontaneous imbibition, and the water in the pores gradually connects to form a “water shield” that blocks the flow of the oil phase. We propose the spontaneous imbibition pathway, which can effectively explain the internal mechanisms controlling the spontaneous imbibition rate. The surface of the core tends to form many spontaneous imbibition pathways, so the rate of spontaneous imbibition is fast. The deep core does not easily form many spontaneous imbibition pathways, so the rate of spontaneous imbibition is slow. This paper reveals the pore characteristics and distribution of oil and water during the spontaneous imbibition process, which is of significance for the efficient development of tight oil. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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13 pages, 3357 KiB  
Article
Investigation into the Classification of Tight Sandstone Reservoirs via Imbibition Characteristics
by Ming Li, Hai’en Yang, Hongjun Lu, Tianjiang Wu, Desheng Zhou and Yafei Liu
Energies 2018, 11(10), 2619; https://doi.org/10.3390/en11102619 - 01 Oct 2018
Cited by 10 | Viewed by 2168
Abstract
Tight sandstone reservoirs are often produced by shutting in the well and inducing imbibition. However, by adopting current reservoir classifications, the heterogeneity of reservoirs cannot be properly treated. Based upon the analysis of the imbibition curves and mercury intrusion porosimetry tests, Chang-7 tight [...] Read more.
Tight sandstone reservoirs are often produced by shutting in the well and inducing imbibition. However, by adopting current reservoir classifications, the heterogeneity of reservoirs cannot be properly treated. Based upon the analysis of the imbibition curves and mercury intrusion porosimetry tests, Chang-7 tight sandstone reservoirs were classified into three categories according to the newly proposed standards. Imbibition tests demonstrated that for the first category, imbibition and drainage occurred continuously and never reached the plateau within the experiment duration. It was suggested that a longer shut-in time favors the production of oil. For the second category, a steady state for imbibition was reached and a shut-in time as short as three days resulted in a high imbibition rate. For the third category, a plateau was reached for the first time and imbibition restarted until a steady state was reached. The average shut-in time for the third category was eight days. Compatibility between reservoir characteristics and a soaking development regime based upon the proposed classification methods effectively enhances the oil recovery efficiency of formations with distinct petrophysical properties. This provides insight into the classification methods of tight sandstone reservoirs. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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12 pages, 4226 KiB  
Article
Effect of Pristine Palygorskite Powders on Explosion Characteristics of Methane-Air Premixed Gas
by Yimin Zhang, Yan Wang, Ligang Zheng, Tao Yang, Jianliang Gao and Zhenhua Li
Energies 2018, 11(10), 2496; https://doi.org/10.3390/en11102496 - 20 Sep 2018
Cited by 14 | Viewed by 2515
Abstract
In this study, pristine palygorskite powders were used as the inhibition materials to suppress the explosion of methane-air premixed gas for the first time. The composition, porosity and pyrolysis characteristics of the powders were tested by X-ray diffraction (XRD), energy dispersive spectrometry (EDS), [...] Read more.
In this study, pristine palygorskite powders were used as the inhibition materials to suppress the explosion of methane-air premixed gas for the first time. The composition, porosity and pyrolysis characteristics of the powders were tested by X-ray diffraction (XRD), energy dispersive spectrometry (EDS), N2 adsorption-desorption and Thermogravimetry-differential scanning calorimetry (TG-DSC) techniques. The effects of pristine palygorskite powders concentration on the explosion pressure and the average velocity of flame propagation of the 9.5% methane-air premixed gas were tested by a 20 L spherical explosion system and a 5 L pipeline explosion system. The results indicated the pristine palygorskite powders possess a considerable suppression property on methane explosion. When the mass concentration of pristine palygorskite powders was 0.20 g·L−1, the max-pressure of methane explosion was decreased by 23.9%. The methane explosion flame propagation velocity was inhibited obviously. Owing to the excellent inhibitory performance and the advantage of low-cost and environmental harmlessness, pristine palygorskite powders are potential new materials for the application on gas explosion suppression. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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Review

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19 pages, 1426 KiB  
Review
Mathematical Modeling and Simulation of Nanoparticle-Assisted Enhanced Oil Recovery—A Review
by Sayed Ameenuddin Irfan, Afza Shafie, Noorhana Yahya and Nooraini Zainuddin
Energies 2019, 12(8), 1575; https://doi.org/10.3390/en12081575 - 25 Apr 2019
Cited by 29 | Viewed by 4674
Abstract
In the last two decades, nanotechnology has flourished due to its vast number of applications in many fields such as drug delivery, oil and gas, and thermal applications, like cooling and air-conditioning. This study focuses on the applications of nanoparticles/nanofluids in the Enhanced [...] Read more.
In the last two decades, nanotechnology has flourished due to its vast number of applications in many fields such as drug delivery, oil and gas, and thermal applications, like cooling and air-conditioning. This study focuses on the applications of nanoparticles/nanofluids in the Enhanced Oil Recovery (EOR) process to increase oil recovery efficiency. To understand the nanoparticle-assisted EOR process, the first step is to understand the flow characteristics of nanoparticles in porous media, including entrapment and release in the pores and the behavior of nanoparticles under high temperatures, pressures, and salinity levels and in the presence of external electric and magnetic fields. Also, the process looks at the roles of various pore distributions during their application as EOR agents. The experimental approaches are not only time consuming, but they are also cumbersome and expensive. Hence, the mathematical models could help to facilitate the understanding of the transport and interaction of nanofluids in a reservoir and how such processes can be optimized to get maximum oil recovery and, in turn, reduce the production cost. This paper reviews and critically analyzes the latest developments in mathematical modeling and simulation techniques that have been reported for nanofluid-assisted EOR. One section is dedicated to discussing the challenges ahead, as well as the research gaps in the modeling approach to help the readers to also contribute to further enlightening the modeling nanofluid-assisted EOR process. Full article
(This article belongs to the Special Issue Latest Research Progress for Nanotech for Oil and Gas)
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