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Shale oil micro-migration characterization: Key methods and outlook
Get PDFResearch has identified and increasingly explored the micro-migration phenomenon in shaly strata, which is currently one of the key scientific issues affecting shale oil accumulation and efficient development. Recently, qualitative and quantitative methods for characterizing hydrocarbon fractionation related to shale oil micro-migration have been proposed, which brought promising prospects to oil micro-migration research. Three key techniques in this field are summarized in this minireview, and the outlook for shale oil micro-migration characterization is prospected. Fourier transform ion cyclotron resonance mass spectrometry can be employed to distinguish subtle composition differences related to short-distance migration; core-flooding extraction experiments can be utilized for the quantitative characterization of micro-migration in organic-rich shale; and semi-open thermal simulation experiments are useful to analyze the chemical composition and structural evolution of expelled and retained oil. These three methods have different focus and advantages, while they provide different viewpoints and means for the characterization of shale oil micro-migration and have all achieved good results in different regions. Studies regarding the latest technologies deepen our understanding of the short-distance migration of shale oil, as well as improve our knowledge of the mechanisms of shale oil micro-migration, which is of great practical significance to the evaluation of shale oil content and mobility and further optimizes the identification of sweet spots and the effects of fracturing development.Document Type: Current minireviewCited as: Hu, T., Jing, Z., Zhang, Q., Pan, Y., Yuan, M., Li, M. Shale oil micro-migration characterization: Key methods and outlook. Advances in Geo-Energy Research, 2025, 15(1): 5-12. https://doi.org/10.46690/ager.2025.01.0
Dissolution patterns prediction for horizontal rough fracture based on deep neural network and lattice Boltzmann method
Get PDFUnderstanding thermal energy transfer and fracture evolution in submarine hydrothermal systems is essential for sustainable resource utilization, but simulating these complex multiphase, multi-physics processes is challenging. This study integrates the lattice Boltzmann method with a fully connected neural network to investigate hydrothermal phase separation and its effects on chemical dissolution in carbonate fractures at the pore scale. Specifically, the lattice Boltzmann method simulates gas-liquid phase separation induced by seawater boiling, affecting carbonate fracture dissolution at the pore scale. The fully connected neural network predicts the resulting fracture geometry and dissolution quantities under various physical conditions. Analysis of simulation datasets demonstrates that the fully connected neural network achieves high predictive accuracy, with a total loss of 0.01 and reduces computation time by over 20% compared to traditional methods. The coupled lattice Boltzmann method-fully connected neural network model effectively simulates fractures with sizes ranging from millimeters to centimeters, excelling in handling chemical dissolution, multiphase flows, and multicomponent interactions. This approach offers valuable predictive capabilities for applications such as enhanced geothermal systems and oil reservoir exploitation.Document Type: Original articleCited as: Yi, G., Zhuang, X., Zhang, D., Li, Y., Gong, L. Dissolution patterns prediction for horizontal rough fracture based on deep neural network and lattice Boltzmann method. Advances in Geo-Energy Research, 2025, 15(3): 273-282. https://doi.org/10.46690/ager.2025.03.0
Effect of confinement on the vapor-liquid-liquid three-phase equilibrium during CO2 utilization and sequestration in shale reservoirs
Get PDFWith the rising global energy demand, shale gas and oil emerge as pivotal resources. Recent innovations utilizing CO2 as an injectant can effectively enhance shale oil and gas recovery and facilitate CO2 storage within shale reservoirs. However, low-temperature CO2 injection may result in the coexistence of three hydrocarbon phases, while the abundant nanopores in shale formations also notably influence the phase behavior of reservoir fluids. To optimize shale oil recovery and CO2 sequestration in shale formations, it is a prerequisite for precisely capturing the effect of confinement on the phase behavior of reservoir fluids within nanopores during CO2 injection. In this work, we introduce a novel three-phase vapor-liquid-liquid equilibrium calculation algorithm, which is designed to handle the unique phase behavior challenges presented by CO2 utilization and storage in shale reservoirs. To improve the robustness and efficiency, the proposed algorithm integrates a trust region-based stability test with a hybrid flash calculation algorithm that combines the Newton-Raphson and trust-region methods. Our thermodynamic model incorporates the capillarity effect and shifts in the critical points due to molecule-wall interactions, which are essential for accurate phase behavior simulation under confinement. Initial validations against experimental bulk phase data show promising results, and further investigations indicate that confinement alters three-phase vapor-liquid-liquid equilibria by suppressing two-phase and three-phase regions and shifting boundaries in the phase diagrams. The proposed algorithm not only advances our understanding of multiphase equilibrium in nanoporous media but also enhances the practicality of CO2 sequestration and improved oil recovery strategies in shale formations.Document Type: Original articleCited as: Chen, Z., Li, R., Du, Y., Ma, S., Zhang, X., Shi, J. Effect of confinement on the vapor-liquid-liquid three-phase equilibrium during CO2 utilization and sequestration in shale reservoirs. Advances in Geo-Energy Research, 2025, 16(3): 199-210. https://doi.org/10.46690/ager.2025.06.0
The microfluidic in geo-energy resources: Current advances and future perspectives
Get PDFThe development of geo-energy resources plays a crucial role in transitioning towards a sustainable energy future and achieving carbon neutrality. Conventional experimental approaches, constrained by macroscopic-scale observations and high costs, often fail to capture critical microscale mechanisms. In contrast, microfluidic technology offers distinct advantages through high-resolution visualization, high-throughput screening, and precise simulation of practical conditions such as temperature, pressure, pore structures, and chemical reactions, effectively addressing key challenges in geo-energy extraction. This review systematically examines innovative applications of microfluidics in shale gas reservoir, carbon capture, utilization and storage, chemical enhanced oil recovery, enhanced geothermal system, and natural gas hydrate. It further investigates prevailing challenges regarding material compatibility, scale translation, and data extrapolation methodologies. The study demonstrates that microfluidic systems provide innovative experimental methodologies, enabling unprecedented precision in elucidating complex geological processes through enhanced mass transfer efficiency and high-throughput screening capabilities, thereby bridging microscale mechanisms with macroscale phenomena. In the future advancements, the microfluidic technology demands synergistic convergence with materials science, chemical reactions, artificial intelligence, and physical explanation to promote the geo-energy research. This interdisciplinary convergence will provide scientific foundation for developing efficient and sustainable energy solutions.Document Type: Invited reviewCited as: Lu, Z., Wang, L., Guo, Z., Hong, Y., Zhang, L. The microfluidic in geo-energy resources: Current advances and future perspectives. Advances in Geo-Energy Research, 2025, 16(2): 171-180. https://doi.org/10.46690/ager.2025.05.08
Interaction of Cu-Al melts with Cr₂AlC and (Cr₀.₉₅Mn₀.₀₅)₂AlC MAX-phases
No full textNew materials based on MAX-phases require methods of soldering, impregnation and knowledge of corrosion resistance to melts at high temperatures. Direct observations of the interaction of melts with MAX-phases provide the most complete information on contact angles, absorption. In our work, high-speed thermal imaging is used, which allows recording thermal effects during the interaction of melts with a solid phase. Melts with aluminum are reactive and dissolve almost all metals. On the other hand, copper allows reducing reactivity by diluting aluminum. This is the reason for choosing copper-aluminum alloys to study corrosion and capillary interaction with the widespread MAX-phases on Cr₂AlC base. The interaction between two-component Al-Cu melts, Cr₂AlC and Cr₀.₉₅Mn₀.₀₅)₂AlC was investigated at temperatures reaching 1,150 ◦C under a vacuum of 10⁻³ Pa. Pure aluminum melt uniformly dissolves MAX-phases at elevated temperatures without wetting it or infiltrating the porous structure. In contrast, interaction with the pure copper melt results in the decomposition of MAX-phases, leading to the formation of a rigid framework composed of chromium carbides, which is impregnated with Cu(Al,Cr) bronze. By adjusting the aluminum content in the copper melt, it is possible to inhibit the complete decomposition of MAX-phases while simultaneously infiltrating and sintering MAX-phases powder to create a mechanically robust composite material.Document Type: Original articleCited as: Zhevnenko, S., Gorshenkov, M., Gorshkov, V. Interaction of Cu-Al melts with Cr₂AlC and (Cr₀.₉₅Mn₀.₀₅)₂AlC MAX-phases. Capillarity, 2025, 15(2): 33-43. https://doi.org/10.46690/capi.2025.05.0
Foam stabilization mechanism of core-shell particles: Insights from the gas-liquid interface theory
Get PDFTo improve oil displacement efficiency under deep reservoir conditions, foam flooding technology represents a critical strategy through the establishment of a stable, long-lasting foam system. A central challenge in this application is to characterize the evolution dynamics of foam under extreme reservoir conditions such as high temperature and salinity. In this study, a performance evaluation experiment of foams generated by different types of surfactants was carried out by using the Waring-blender method. The foam stability characteristics were analyzed on the basis of foam volume, half-life of the liquid solution, and the foam comprehensive index and other related parameters. Based on the microscopic action mechanism of gas-liquid interface, the change pattern of foam performance with concentration, salinity and the coordinated action of core-shell particles were investigated. Both candidate surfactants exhibited good resistance to temperature and salinity. Among them, one surfactant demonstrated superior overall performance, with the foam comprehensive index reaching its peak at an optimal mass concentration of 0.5%. In high-salinity environments, the synergistic interaction between core-shell particles and surfactant molecules significantly enhances foam stability. In particular, the combination of this surfactant with core-shell particles at a mass fraction of 0.5% resulted in a notably higher foam comprehensive index, suggesting its strong application potential. This study quantitatively analyzes the synergistic stability effects of salinity, core-shell particles and surfactant, and reveals the synergistic stability mechanism of salt ion compression electric double layer and particle interface adsorption, providing important theoretical guidance for the development and application of deep reservoir foam flooding.Document Type: Original articleCited as: Xu, Z., Ding, G., Tao, L. Shi, W., Bai, J., Dang, F. Foam stabilization mechanism of core-shell particles: Insights from the gas-liquid interface theory. Capillarity, 2025, 16(1): 5-17. https://doi.org/10.46690/capi.2025.07.0
Digital rock physics and resistivity well logging interpretation in unconventional reservoirs: Advances and prospects
Get PDFUnconventional hydrocarbon reservoirs, characterized by multiscale and complex pore architectures, diverse mineralogical compositions, and pronounced heterogeneity, present significant limitations to conventional saturation estimation and reservoir evaluation methods, with resistivity well logging data based on classic models such as Archie’s equations. Digital rock physics technology, integrating multi-scale imaging, three-dimensional reconstruction, and numerical simulation, enables the precise characterization of pore structures and conductive mechanisms, markedly enhancing the accuracy of electrical response simulations and well logging evaluations in complex reservoirs. Through this perspective, this study systematically compares the application limitations and associated impacts of conventional resistivity logging in unconventional reservoirs of various lithologies and evaluates the applicability and merits of distinct rock physics numerical simulation approaches, highlighting existing constraints and challenges. Furthermore, this work outlines future directions for integrating digital rock physics with well logging evaluation.Document Type: PerspectiveCited as: Nie, X., Song, J., Wei, W., Cai, J. Digital rock physics and resistivity well logging interpretation in unconventional reservoirs: Advances and prospects . Advances in Geo-Energy Research, 2025, 18(3): 287-290. https://doi.org/10.46690/ager.2025.12.0
Characterization and simulation of underground hydrogen storage across scales
Get PDFUnderground hydrogen storage has emerged as a pivotal component of the low-carbon energy transition, providing a viable solution to the intermittency of renewable energy sources. The distinctive physical and chemical properties of hydrogen, together with its interactions with surrounding rocks and fluids, introduce unique challenges for subsurface storage. This perspective presents recent advances in experimental and modeling efforts of underground hydrogen storage from a multi-scale perspective, highlighting that established methods from hydrocarbon recovery and carbon dioxide storage remain valuable for studying hydrogen systems, yet effectively translating and scaling the relevant physical processes requires renewed attention. Improving the purity and recovery efficiency of stored hydrogen will be central to guiding future reseach on hydrogen storage in geological porous media.Document Type: Original articleCited as: Zhao, Q., Bo, Z., Pan, B., Wang, Y. Characterization and simulation of underground hydrogen storage across scales. Advances in Geo-Energy Research, 2025, 18(2): 195-198. https://doi.org/10.46690/ager.2025.11.08
Digital rock physics and fluid flow in the context of the energy transition
Get PDFOn November 16, 2025, the editorial office of Advances in Geo-Energy Research (AGER) successfully held the 100th AGER Forum, jointly supported by several academic partners, and attended by more than 10,000 people online. With the theme focusing “Digital rock physics and fluid flow in the context of energy transition”, the event gathered renowned experts from UK, Belgium and China to discuss frontier progress in fluid flow, pore-scale simulation, and geo-energy storage research. The forum emphasized that digital rock physics and multiscale imaging technologies are becoming essential research tools in next-generation low-carbon energy systems. The AGER forum included expert lectures and interactive discussions, enhancing the influence of AGER within the global geo-energy f ield. The 100th Forum marks an important milestone in the development of the journal. In the future, the AGER Forum will continue serving as a platform for advancing science and technology in the field of geo-energy.Document Type: PerspectiveCited as: Blunt, M. J., Sun, S., Boone, M. A., Zhang, L., Cai, J. Digital rock physics and fluid flow in the context of the energy transition. Advances in Geo-Energy Research, 2025, 18(3): 299-302. https://doi.org/10.46690/ager.2025.12.1
Pressure heterogeneity caused by fluid injection and diffusion controls occurrence of induced earthquakes
Get PDFUnderground fluid-injection operations, such as hydraulic fracturing and enhanced geothermal stimulation, have triggered multiple earthquakes across the globe. Earthquake nucleation models within the rate-and-state friction framework suggest that an increase in fluid pressure favors stable slip. However, certain observations indicate that fluid injected into faults may reduce effective normal stress, promoting fault failure, which highlights the debate on the role of fluids in controlling earthquake fault stability. This paper proposes a rate-and-state friction-based model of earthquake nucleation that incorporates fluid injection and diffusion processes, and extends the stability criteria of the system. The results show that fluid pressure heterogeneity can indeed influence fault stability. Elevated fluid pressure stabilizes faults, however, fluid pressure heterogeneity counteracts this stabilizing effect. The model suggests that pressure heterogeneity above a certain threshold facilitates seismic slip, whereas heterogeneity below this threshold can stabilize it. The results further indicate that this threshold reflects a universal instability criterion inherent to the system, rather than an incidental product of a specific fault or rock type. Accordingly, this study proposes a pressure-heterogeneity index as an operational precursor: Tracking spatiotemporal pore-pressure heterogeneity can guide the traffic-light-style adaptive control of injection. These insights provide a new, mechanism-based explanation for the role of fluids in triggering earthquakes.Document Type: Original articleCited as: Han, S., Zhuang, X., Zhou, Q., Feng, X., Hu, X., Yao, Q. Pressure heterogeneity caused by fluid injection and diffusion controls occurrence of induced earthquakes. Advances in Geo-Energy Research, 2025, 18(3): 242-256. https://doi.org/10.46690/ager.2025.12.0