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Minerals
Special Issues
Deep Saline CO2 Sequestration: Mechanisms and Coupling Behaviours
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Deep Saline CO2 Sequestration: Mechanisms and Coupling Behaviours

A special issue of Minerals (ISSN 2075-163X). This special issue belongs to the section "Environmental Mineralogy and Biogeochemistry".

Deadline for manuscript submissions: closed (16 October 2020) | Viewed by 5541

Special Issue Editors

Dr. Tharaka Rathnaweera

E-Mail Website
Guest Editor
Department of Civil Engineering, Monash University Clayton Campus, Melbourne, Australia
Interests: geological sequestration; geotechnical engineering; nano-injection; geothermal energy; hydraulic fracturing; proppant behavior; coal seam gas; reservoir rock; saline aquifers
Dr. Junlong Shang

E-Mail Website
Guest Editor
James Watt School of Engineering, University of Glasgow, Glasgow G12 8QQ, UK
Interests: rock mechanics; geotechnical engineering; geothermal energy; mining engineering; underground space; machine learning; discrete element method

Special Issue Information

Dear Colleagues,

Current and historical human activities, including energy production by the burning of fossil fuels, unsustainable agriculture activities, and land use changes, have escalated levels of greenhouse gases in the atmosphere. The anthropogenic contribution to these gases has led to their augmented concentrations in the atmosphere and global warming associated with the greenhouse effect. Of the various greenhouse gases, it is CO2 and its abundance in the atmosphere that humanity is best positioned to control. Plans for action to mitigate the effects of global warming have thus concentrated on the reduction of CO2 emission into the atmosphere.

Geological CO2 sequestration has been routinely proposed by many countries to control their elevated levels of anthropogenic CO2 in the atmosphere. CO2 sequestration in deep saline aquifers offers an innovative and ingenious way to combat increased emissions. Deep saline repositories have the largest estimated storage capacity, being widely distributed throughout the globe in all sedimentary basins. However, there is considerable uncertainty regarding the achievable storage capacity of deep saline aquifers because of limited data on the physical and chemical interactions that occur among brine, rock, and CO2 at the pressures and temperatures relevant to deep storage. In addition, the slow solubility of injected CO2 in brine is considered to be one of the fundamental drawbacks, making conventional versions of the process inefficient and uneconomical. Therefore, further understanding of these complex interactions is needed before deep saline aquifer sequestration can be pursued at the industrial scale required for effective CO2 emission reductions.

This Special Issue aims to explore these issues and thus make a significant contribution to deep saline CO2 sequestration. Our target is to identify recent advances in understanding, monitoring, and modelling of coupled chemico-mineralogical-thermo-hydro-mechanical (CMTHM) processes in deep saline aquifers and to apply these processes to realistically assess the feasibility of large-scale CO2 storage in deep saline reservoirs. We look forward to receiving comprehensive reviews, nano/micro to macro scale experimental evaluations and field studies, and analytical and numerical techniques related to deep saline CO2 sequestration.

Dr. Tharaka Rathnaweera
Dr. Junlong Shang
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. Minerals 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 2400 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

  • Trapping mechanisms
  • Storage enhancement techniques
  • Hydro-mechanical behaviour
  • Chemico-mineralogical responses
  • Complex coupling behaviours
  • Caprock integrity
  • CO2 plume development and characterisation
  • Leakage risk
  • Seismic response

Published Papers (2 papers)

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Research

29 pages, 73117 KiB  
Article
Advanced Geomechanical Model to Predict the Impact of CO2-Induced Microstructural Alterations on the Cohesive-Frictional Behavior of Mt. Simon Sandstone
by Ange-Therese Akono, Charles Werth, Zhuofan Shi, Kristian Jessen and Theodore T. Tsotsis
Minerals 2021, 11(1), 38; https://doi.org/10.3390/min11010038 - 31 Dec 2020
Cited by 3 | Viewed by 2716
Abstract
We investigated the influence of CO2-induced geochemical reactions on the cohesive-frictional properties of host rock within the context of CO2 storage in a saline aquifer and focused on the Mt. Simon sandstone. The research objective was to model geo-mechanical changes [...] Read more.
We investigated the influence of CO2-induced geochemical reactions on the cohesive-frictional properties of host rock within the context of CO2 storage in a saline aquifer and focused on the Mt. Simon sandstone. The research objective was to model geo-mechanical changes due to host rock exposure to CO2-saturated brine while accounting for heterogeneity, double-scale porosity, and granular structure. We formulated a three-level multi-scale model for host rocks. We conducted scanning electron microscopy analyses to probe the microstructure and grid nanoindentation to measure the mechanical response. We derived new nonlinear strength upscaling solutions to correlate the effective strength characteristics and the macroscopic yield surface to the micro-structure at the nano-, micro-, and meso-scales. Specifically, our theoretical model links CO2-induced microstructural alterations to a reduction in the size of the yield surface, and a drop in the value of the friction coefficient. In turn, regarding the Illinois Basin Decatur Project, the CO2-induced drop in friction coefficient is linked to an increase in the risk of fault slip and a higher probability of induced microseismicity during and after the end of CO2 underground injection operations. The theoretical model presented is essential for the geo-mechanical modeling of CO2 underground injection operations at multiple length-scales. Full article
(This article belongs to the Special Issue Deep Saline CO2 Sequestration: Mechanisms and Coupling Behaviours)
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16 pages, 4125 KiB  
Article
Fracture Propagation and Morphology Due to Non-Aqueous Fracturing: Competing Roles between Fluid Characteristics and In Situ Stress State
by Yunzhong Jia, Zhaohui Lu, Hong Liu, Jiehao Wang, Yugang Cheng and Xinwei Zhang
Minerals 2020, 10(5), 428; https://doi.org/10.3390/min10050428 - 10 May 2020
Cited by 7 | Viewed by 2403
Abstract
Non-aqueous or gaseous stimulants are alternative working fluids to water for hydraulic fracturing in shale reservoirs, which offer advantages including conserving water, avoiding clay swelling and decreasing formation damage. Hence, it is crucial to understand fluid-driven fracture propagation and morphology in shale formations. [...] Read more.
Non-aqueous or gaseous stimulants are alternative working fluids to water for hydraulic fracturing in shale reservoirs, which offer advantages including conserving water, avoiding clay swelling and decreasing formation damage. Hence, it is crucial to understand fluid-driven fracture propagation and morphology in shale formations. In this research, we conduct fracturing experiments on shale samples with water, liquid carbon dioxide, and supercritical carbon dioxide to explore the effect of fluid characteristics and in situ stress on fracture propagation and morphology. Moreover, a numerical model that couples rock property heterogeneity, micro-scale damage and fluid flow was built to compare with experimental observations. Our results indicate that the competing roles between fluid viscosity and in situ stress determine fluid-driven fracture propagation and morphology during the fracturing process. From the macroscopic aspect, fluid-driven fractures propagate to the direction of maximum horizontal stress direction. From the microscopic aspect, low viscosity fluid easily penetrates into pore throats and creates branches and secondary fractures, which may deflect the main fracture and eventually form the fracture networks. Our results provide a new understanding of fluid-driven fracture propagation, which is beneficial to fracturing fluid selection and fracturing strategy optimization for shale gas hydraulic fracturing operations. Full article
(This article belongs to the Special Issue Deep Saline CO2 Sequestration: Mechanisms and Coupling Behaviours)
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