1
|
Wei-Hsin Sun E, Bourg IC. Impact of organic solutes on capillary phenomena in water-CO2-quartz systems. J Colloid Interface Sci 2022; 629:265-275. [DOI: 10.1016/j.jcis.2022.08.124] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 06/16/2022] [Revised: 08/17/2022] [Accepted: 08/18/2022] [Indexed: 11/29/2022]
|
2
|
Nhunduru RAE, Jahanbakhsh A, Shahrokhi O, Wlodarczyk KL, Garcia S, Maroto‐Valer MM. The Impact of Wettability on Dynamic Fluid Connectivity and Flow Transport Kinetics in Porous Media. WATER RESOURCES RESEARCH 2022; 58:e2021WR030729. [PMID: 35859620 PMCID: PMC9285789 DOI: 10.1029/2021wr030729] [Citation(s) in RCA: 2] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Key Words] [Grants] [Track Full Text] [Figures] [Subscribe] [Scholar Register] [Received: 07/01/2021] [Revised: 05/09/2022] [Accepted: 05/13/2022] [Indexed: 06/15/2023]
Abstract
Usually, models describing flow and transport for sub-surface engineering processes at the Darcy-scale do not take into consideration the effects of pore-scale flow regimes and fluid connectivity on average flow functions. In this article, we investigate the impact of wettability on pore-scale flow regimes. We show that fluid connectivity at the pore scale has a significant impact on average flow kinetics and therefore its contribution should not be ignored. Immiscible two-phase flow simulations were performed in a two-dimensional model of a Berea sandstone rock for wettability conditions ranging from moderately water-wet to strongly oil-wet. The simulation results show that wettability has a strong impact on invading fluid phase connectivity, which subsequently influences flow transport resistance. The effect of invading-phase connectivity and ganglion dynamics (GD) on two-phase displacement kinetics was also investigated. It was found that invading phase connectivity decreases away from the neutrally wet (intermediate wet) state. This study provides evidence that GD accelerate fluid flow transport kinetics during immiscible displacement processes. Lastly, the impact of wettability on fluid displacement efficiency and residual saturations was investigated. Maximum displacement efficiency occurred at the neutrally wet state.
Collapse
Affiliation(s)
- Rumbidzai A. E. Nhunduru
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
| | - Amir Jahanbakhsh
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
| | - Omid Shahrokhi
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
| | - Krystian L. Wlodarczyk
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
- School of Engineering and Physical SciencesApplied Optics and Photonics (AOP) GroupHeriot‐Watt UniversityEdinburghUK
| | - Susana Garcia
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
| | - M. Mercedes Maroto‐Valer
- School of Engineering and Physical SciencesResearch Centre for Carbon Solutions (RCCS)Heriot‐Watt UniversityEdinburghUK
| |
Collapse
|
3
|
Live imaging of micro and macro wettability variations of carbonate oil reservoirs for enhanced oil recovery and CO 2 trapping/storage. Sci Rep 2022; 12:1262. [PMID: 35075172 PMCID: PMC8786969 DOI: 10.1038/s41598-021-04661-2] [Citation(s) in RCA: 2] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 10/08/2021] [Accepted: 12/28/2021] [Indexed: 11/09/2022] Open
Abstract
Carbonate hydrocarbon reservoirs are considered as potential candidates for chemically enhanced oil recovery and for CO2 geological storage. However, investigation of one main controlling parameter-wettability-is usually performed by conventional integral methods at the core-scale. Moreover, literature reports show that wettability distribution may vary at the micro-scale due to the chemical heterogeneity of the reservoir and residing fluids. These differences may profoundly affect the derivation of other reservoir parameters such as relative permeability and capillary pressure, thus rendering subsequent simulations inaccurate. Here we developed an innovative approach by comparing the wettability distribution on carbonates at micro and macro-scale by combining live-imaging of controlled condensation experiments and X-ray mapping with sessile drop technique. The wettability was quantified by measuring the differences in contact angles before and after aging in palmitic, stearic and naphthenic acids. Furthermore, the influence of organic acids on wettability was examined at micro-scale, which revealed wetting heterogeneity of the surface (i.e., mixed wettability), while corresponding macro-scale measurements indicated hydrophobic wetting properties. The thickness of the adsorbed acid layer was determined, and it was correlated with the wetting properties. These findings bring into question the applicability of macro-scale data in reservoir modeling for enhanced oil recovery and geological storage of greenhouse gases.
Collapse
|
4
|
Ali M, Awan FUR, Ali M, Al-Yaseri A, Arif M, Sánchez-Román M, Keshavarz A, Iglauer S. Effect of humic acid on CO2-wettability in sandstone formation. J Colloid Interface Sci 2021; 588:315-325. [DOI: 10.1016/j.jcis.2020.12.058] [Citation(s) in RCA: 50] [Impact Index Per Article: 16.7] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 10/13/2020] [Revised: 12/16/2020] [Accepted: 12/17/2020] [Indexed: 11/27/2022]
|
5
|
Cheng X, Lu R, Zhang X, Zhu Y, Wei S, Zhang Y, Zan X, Geng W, Zhang L. Silanization of a Metal-Polyphenol Coating onto Diverse Substrates as a Strategy for Controllable Wettability with Enhanced Performance to Resist Acid Corrosion. LANGMUIR : THE ACS JOURNAL OF SURFACES AND COLLOIDS 2021; 37:3637-3647. [PMID: 33740370 DOI: 10.1021/acs.langmuir.0c03623] [Citation(s) in RCA: 6] [Impact Index Per Article: 2.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 06/12/2023]
Abstract
Wettability is a crucial characteristic of materials that plays a vital role in surface engineering. Surface modification is the key to changing the wettability of materials, and a simple and universal modification approach is being extensively pursued by researchers. Recently, metal-phenolic networks (MPNs) have been widely studied because they impart versatility and functionality in surface modification. However, an MPN is not stable for long periods, especially under acidic conditions, and is susceptible to pollution by invasive species. Spurred by the versatility of MPNs and various functionalities achieved by silanization, we introduce a general strategy to fabricate functionally stable coatings with controllable surface wettability by combining the two methods. The formation process of MPN and silane-MPN coatings was characterized by spectroscopic ellipsometry (SE), UV-visible-near-infrared (UV-vis-NIR) spectroscopy, X-ray photoelectron spectroscopy (XPS), scanning electron microscopy (SEM), atomic force microscopy (AFM), water contact angle (WCA), etc. We found that the stability of the MPN was greatly enhanced after silanization, which is attributed to the cross-linking effect that occurs between silane and the MPN, namely, the cross-linking protection produced in this case. Additionally, the wettability of an MPN can be easily changed through our strategy. We trust that our strategy can further extend the applications of MPNs and points toward potential prospects in surface modification.
Collapse
Affiliation(s)
- Xinxiu Cheng
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
- University of Chinese Academy of Sciences, Beijing 100049, People's Republic of China
| | - Ruofei Lu
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
- University of Chinese Academy of Sciences, Beijing 100049, People's Republic of China
| | - Xiaoqiang Zhang
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
- University of Chinese Academy of Sciences, Beijing 100049, People's Republic of China
| | - Yaxin Zhu
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
| | - Shaoyin Wei
- School of Ophthalmology and Optometry, Eye Hospital, School of Biomedical Engineering, Wenzhou Medical University, 270 Xueyuan Road, Wenzhou 325035, People's Republic of China
| | - Yagang Zhang
- School of Materials and Energy, University of Electronic Science and Technology of China, Chengdu 611731, People's Republic of China
| | - Xingjie Zan
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
- University of Chinese Academy of Sciences, Beijing 100049, People's Republic of China
| | - Wujun Geng
- Department of Anesthesiology, The First Affiliated Hospital of Wenzhou Medical University, Wenzhou 325000, People's Republic of China
| | - Letao Zhang
- Xinjiang Technical Institute of Physics and Chemistry, Chinese Academy of Sciences, Urumqi 830011, People's Republic of China
| |
Collapse
|
6
|
Upscaling the porosity-permeability relationship of a microporous carbonate for Darcy-scale flow with machine learning. Sci Rep 2021; 11:2625. [PMID: 33514764 PMCID: PMC7846807 DOI: 10.1038/s41598-021-82029-2] [Citation(s) in RCA: 24] [Impact Index Per Article: 8.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 09/23/2020] [Accepted: 12/23/2020] [Indexed: 11/17/2022] Open
Abstract
The permeability of a pore structure is typically described by stochastic representations of its geometrical attributes (e.g. pore-size distribution, porosity, coordination number). Database-driven numerical solvers for large model domains can only accurately predict large-scale flow behavior when they incorporate upscaled descriptions of that structure. The upscaling is particularly challenging for rocks with multimodal porosity structures such as carbonates, where several different type of structures (e.g. micro-porosity, cavities, fractures) are interacting. It is the connectivity both within and between these fundamentally different structures that ultimately controls the porosity–permeability relationship at the larger length scales. Recent advances in machine learning techniques combined with both numerical modelling and informed structural analysis have allowed us to probe the relationship between structure and permeability much more deeply. We have used this integrated approach to tackle the challenge of upscaling multimodal and multiscale porous media. We present a novel method for upscaling multimodal porosity–permeability relationships using machine learning based multivariate structural regression. A micro-CT image of Estaillades limestone was divided into small 603 and 1203 sub-volumes and permeability was computed using the Darcy–Brinkman–Stokes (DBS) model. The microporosity–porosity–permeability relationship from Menke et al. (Earth Arxiv, https://doi.org/10.31223/osf.io/ubg6p, 2019) was used to assign permeability values to the cells containing microporosity. Structural attributes (porosity, phase connectivity, volume fraction, etc.) of each sub-volume were extracted using image analysis tools and then regressed against the solved DBS permeability using an Extra-Trees regression model to derive an upscaled porosity–permeability relationship. Ten test cases of 3603 voxels were then modeled using Darcy-scale flow with this machine learning predicted upscaled porosity–permeability relationship and benchmarked against full DBS simulations, a numerically upscaled Darcy flow model, and a Kozeny–Carman model. All numerical simulations were performed using GeoChemFoam, our in-house open source pore-scale simulator based on OpenFOAM. We found good agreement between the full DBS simulations and both the numerical and machine learning upscaled models, with the machine learning model being 80 times less computationally expensive. The Kozeny–Carman model was a poor predictor of upscaled permeability in all cases.
Collapse
|
7
|
Yekeen N, Padmanabhan E, Sevoo TA, Kanesen KA, Okunade OA. Wettability of rock/CO2/brine systems: A critical review of influencing parameters and recent advances. J IND ENG CHEM 2020. [DOI: 10.1016/j.jiec.2020.03.021] [Citation(s) in RCA: 30] [Impact Index Per Article: 7.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/12/2022]
|
8
|
Scanziani A, Lin Q, Alhosani A, Blunt MJ, Bijeljic B. Dynamics of fluid displacement in mixed-wet porous media. Proc Math Phys Eng Sci 2020; 476:20200040. [PMID: 32922149 PMCID: PMC7482207 DOI: 10.1098/rspa.2020.0040] [Citation(s) in RCA: 12] [Impact Index Per Article: 3.0] [Reference Citation Analysis] [Abstract] [Key Words] [Grants] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 01/22/2020] [Accepted: 06/24/2020] [Indexed: 11/12/2022] Open
Abstract
We identify a distinct two-phase flow invasion pattern in a mixed-wet porous medium. Time-resolved high-resolution synchrotron X-ray imaging is used to study the invasion of water through a small rock sample filled with oil, characterized by a wide non-uniform distribution of local contact angles both above and below 90°. The water advances in a connected front, but throats are not invaded in decreasing order of size, as predicted by invasion percolation theory for uniformly hydrophobic systems. Instead, we observe pinning of the three-phase contact between the fluids and the solid, manifested as contact angle hysteresis, which prevents snap-off and interface retraction. In the absence of viscous dissipation, we use an energy balance to find an effective, thermodynamic, contact angle for displacement and show that this angle increases during the displacement. Displacement occurs when the local contact angles overcome the advancing contact angles at a pinned interface: it is wettability which controls the filling sequence. The product of the principal interfacial curvatures, the Gaussian curvature, is negative, implying well-connected phases which is consistent with pinning at the contact line while providing a topological explanation for the high displacement efficiencies in mixed-wet media.
Collapse
Affiliation(s)
- Alessio Scanziani
- Department of Earth Science and Engineering, Imperial College London, SW7 2AZ London, UK
| | | | | | | | | |
Collapse
|
9
|
Ali M, Sahito MF, Jha NK, Arain ZUA, Memon S, Keshavarz A, Iglauer S, Saeedi A, Sarmadivaleh M. Effect of nanofluid on CO2-wettability reversal of sandstone formation; implications for CO2 geo-storage. J Colloid Interface Sci 2020; 559:304-312. [DOI: 10.1016/j.jcis.2019.10.028] [Citation(s) in RCA: 65] [Impact Index Per Article: 16.3] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 07/10/2019] [Revised: 10/07/2019] [Accepted: 10/08/2019] [Indexed: 10/25/2022]
|
10
|
Arif M, Abu-Khamsin SA, Iglauer S. Wettability of rock/CO 2/brine and rock/oil/CO 2-enriched-brine systems:Critical parametric analysis and future outlook. Adv Colloid Interface Sci 2019; 268:91-113. [PMID: 30999164 DOI: 10.1016/j.cis.2019.03.009] [Citation(s) in RCA: 29] [Impact Index Per Article: 5.8] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/25/2018] [Revised: 03/10/2019] [Accepted: 03/31/2019] [Indexed: 11/17/2022]
Abstract
CO2 geo-sequestration is a promising technology to permanently store CO2 in geological formations to control the atmospheric carbon footprint. In addition, CO2 is frequently utilized in enhanced oil recovery operations to accelerate oil production. Both, CO2 geo-storage and EOR, are significantly influenced by the wettability of the associated rock/CO2/brine systems. Wettability drives the multiphase flow dynamics, and microscopic fluid distribution in the reservoir. Furthermore, while wettability is known to be influenced by varying in-situ conditions and surface chemistry of the rock/mineral, the current state-of-the-art indicates wider variabilities of the wetting states. This article, therefore, critically reviews the published datasets on CO2 wettability of geological formations. Essentially, the rock/CO2/brine and rock/crude-oil/CO2-enriched-brine contact angle datasets for the important reservoir rocks (i.e. sandstone and carbonate rocks), as well as for the key minerals quartz and calcite are considered. Also, the parameters that influence wettability are critically analyzed, and the associated parametric trends are discussed and summarized. Finally, we identify pertinent research gaps and define the outlook of future research. The review, therefore, establishes a repository of the recent contact angle data, which thus assists to enhance our current understanding of the subject.
Collapse
Affiliation(s)
- Muhammad Arif
- College of Petroleum Engineering and Geosciences, King Fahd University of Petroleum & Minerals (KFUPM), Dhahran, Saudi Arabia.
| | - Sidqi A Abu-Khamsin
- College of Petroleum Engineering and Geosciences, King Fahd University of Petroleum & Minerals (KFUPM), Dhahran, Saudi Arabia
| | - Stefan Iglauer
- School of Engineering, Edith Cowan University (ECU), Joondalup, WA, Australia
| |
Collapse
|
11
|
Ali M, Al-Anssari S, Arif M, Barifcani A, Sarmadivaleh M, Stalker L, Lebedev M, Iglauer S. Organic acid concentration thresholds for ageing of carbonate minerals: Implications for CO2 trapping/storage. J Colloid Interface Sci 2019; 534:88-94. [DOI: 10.1016/j.jcis.2018.08.106] [Citation(s) in RCA: 64] [Impact Index Per Article: 12.8] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 07/10/2018] [Revised: 08/28/2018] [Accepted: 08/28/2018] [Indexed: 10/28/2022]
|
12
|
Al-Anssari S, Barifcani A, Keshavarz A, Iglauer S. Impact of nanoparticles on the CO 2-brine interfacial tension at high pressure and temperature. J Colloid Interface Sci 2018; 532:136-142. [PMID: 30077827 DOI: 10.1016/j.jcis.2018.07.115] [Citation(s) in RCA: 12] [Impact Index Per Article: 2.0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 06/06/2018] [Revised: 07/26/2018] [Accepted: 07/26/2018] [Indexed: 10/28/2022]
Abstract
HYPOTHESIS Nanofluid flooding has been identified as a promising method for enhanced oil recovery (EOR) and improved Carbon geo-sequestration (CGS). However, it is unclear how nanoparticles (NPs) influence the CO2-brine interfacial tension (γ), which is a key parameter in pore-to reservoirs-scale fluid dynamics, and consequently project success. The effects of pressure, temperature, salinity, and NPs concentration on CO2-silica (hydrophilic or hydrophobic) nanofluid γ was thus systematically investigated to understand the influence of nanofluid flooding on CO2 geo-storage. EXPERIMENTS Pendant drop method was used to measure CO2/nanofluid γ at carbon storage conditions using high pressure-high temperature optical cell. FINDINGS CO2/nanofluid γ was increased with temperature and decreased with increased pressure which is consistent with CO2/water γ. The hydrophilicity of NPs was the major factor; hydrophobic silica NPs significantly reduced γ at all investigated pressures and temperatures while hydrophilic NPs showed only minor influence on γ. Further, increased salinity which increased γ can also eliminate the influence of NPs on CO2/nanofluid γ. Hence, CO2/brine γ has low, but, reasonable values (higher than 20 mN/m) at carbon storage conditions even with the presence of hydrophilic NPs, therefore, CO2 storage can be considered in oil reservoirs after flooding with hydrophilic nanofluid. The findings of this study provide new insights into nanofluids applications for enhanced oil recovery and carbon geosequestration projects.
Collapse
Affiliation(s)
- Sarmad Al-Anssari
- School of Engineering, Edith Cowan University, Joondalup, Australia; Department of Chemical Engineering, College of Engineering, University of Baghdad, Iraq; Department of Chemical Engineering, Curtin University, Perth, Australia.
| | - Ahmed Barifcani
- Department of Chemical Engineering, Curtin University, Perth, Australia
| | | | - Stefan Iglauer
- School of Engineering, Edith Cowan University, Joondalup, Australia
| |
Collapse
|
13
|
Iglauer S, Lebedev M. High pressure-elevated temperature x-ray micro-computed tomography for subsurface applications. Adv Colloid Interface Sci 2018. [PMID: 29526246 DOI: 10.1016/j.cis.2017.12.009] [Citation(s) in RCA: 35] [Impact Index Per Article: 5.8] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/18/2022]
Abstract
Physical, chemical and mechanical pore-scale (i.e. micrometer-scale) mechanisms in rock are of key importance in many, if not all, subsurface processes. These processes are highly relevant in various applications, e.g. hydrocarbon recovery, CO2 geo-sequestration, geophysical exploration, water production, geothermal energy production, or the prediction of the location of valuable hydrothermal deposits. Typical examples are multi-phase flow (e.g. oil and water) displacements driven by buoyancy, viscous or capillary forces, mineral-fluid interactions (e.g. mineral dissolution and/or precipitation over geological times), geo-mechanical rock behaviour (e.g. rock compaction during diagenesis) or fines migration during water production, which can dramatically reduce reservoir permeability (and thus reservoir performance). All above examples are 3D processes, and 2D experiments (as traditionally done for micro-scale investigations) will thus only provide qualitative information; for instance the percolation threshold is much lower in 3D than in 2D. However, with the advent of x-ray micro-computed tomography (μCT) - which is now routinely used - this limitation has been overcome, and such pore-scale processes can be observed in 3D at micrometer-scale. A serious complication is, however, the fact that in the subsurface high pressures and elevated temperatures (HPET) prevail, due to the hydrostatic and geothermal gradients imposed upon it. Such HPET-reservoir conditions significantly change the above mentioned physical and chemical processes, e.g. gas density is much higher at high pressure, which strongly affects buoyancy and wettability and thus gas distributions in the subsurface; or chemical reactions are significantly accelerated at increased temperature, strongly affecting fluid-rock interactions and thus diagenesis and deposition of valuable minerals. It is thus necessary to apply HPET conditions to the aforementioned μCT experiments, to be able to mimic subsurface conditions in a realistic way, and thus to obtain reliable results, which are vital input parameters required for building accurate larger-scale reservoir models which can predict the overall reservoir-scale (hectometer-scale) processes (e.g. oil production or diagenesis of a formation). We thus describe here the basic workflow of such HPET-μCT experiments, equipment requirements and apparatus design; and review the literature where such HPET-μCT experiments were used and which phenomena were investigated (these include: CO2 geo-sequestration, oil recovery, gas hydrate formation, hydrothermal deposition/reactive flow). One aim of this paper is to give a guideline to users how to set-up a HPET-μCT experiment, and to provide a quick overview in terms of what is possible and what not, at least up to date. As a conclusion, HPET-μCT is a valuable tool when it comes to the investigation of subsurface micrometer-scaled processes, and we expect a rapidly expanding usage of HPET-μCT in subsurface engineering and the subsurface sciences.
Collapse
|