Evaluation of surface diffusion in microporous/mesoporous media using a numerical model applied to rate-of-adsorption data: Implications for improved gas permeability estimation in shales/tight rocks using drill cuttings

Yang, Zhengru; Clarkson, Christopher R.; Ghanizadeh, Amin

doi:10.1016/j.fuel.2020.118974

Cited by 17 publications

(13 citation statements)

References 82 publications

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“…This schematic illustrates that gas can diffuse into the kerogen and be absorbed by kerogen. Yang et al 119 used accessible horizontal wells drill cuttings to integrate experimental and simulation works to evaluate the permeability and surface diffusion. Their work examined the importance of surface diffusion in various adsorbate/adsorbent procedures.…”

Section: Gas-eor Mechanism In Shale/tightmentioning

confidence: 99%

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

et al. 2021

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In recent times, particularly in the 21st century, there has been an alarming increase in the demand for global energy, along with continuous depletion in conventional oil reservoirs. This necessity has incentivized interested scholars and operators worldwide to seek alternative oil resources. To secure such accelerating energy demand, considerable effort has been directed toward the development of previously unconventional oil formations that, in past decades, had remained sidelined. Although shale oil reservoirs have seen tremendous success over the past decade, the continued challenges of rapidly declining oil flow rates and oil retention in the pores continuously persist. Substantial attempts have been made to improve shale-bypassed oil recovery; however, there is little data about the accessibility on recovery mechanisms, especially in the oil field. Furthermore, approachesparticularly, Huff-n-Puff (H-n-P) experiments using conventional proceduresfail to properly represent field conditions and they generate deceptive findings, because the utilized cores are not simulated under realistic reservoir conditions, leaving the significance of critical factors unclear. Therefore, this review study comprehensively and specifically discusses the feasibility of enhanced oil recovery (EOR) methods in unconventional oil reservoirs. Beside addressing the validity of the currently applied H-n-P technology in shale/tight oil reservoirs and underlining some critical gaps regarding laboratory results, modified technology is proposed in this paper for a better field future performance. The study is divided into sections, and each section analyzes the role of one specific H-n-P portion in detail, such as preferable injected solvents, their mechanisms, and critical factors affecting H-n-P recovery. The exceptions to this are the first and second sections, which provide a brief introduction about shale and tight oil reservoirs, a history of applied technology, and the method’s current problem statement. In the Introduction section, the authors will justify why this Review fills a critical gap in the field. Within the assessment study, great focus is given to the H-n-P technique, its parameters, and effective processes. In the final sections, carefully chosen experimental results and tools are reviewed to highlight the controversy and state “the gap”.

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Section: Gas-eor Mechanism In Shale/tightmentioning

confidence: 99%

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

et al. 2021

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“…The effective micropore diffusivity is from 2.13 × 10 –7 to 7.65 × 10 –5 s –1 , which is also comparable to the effective micropore diffusivity from the literature (2.3 × 10 –7 to 2.37 × 10 –5 s –1 ). , Moreover, CO 2 diffusivity is larger than CH 4 diffusivity under the same pressure step. The faster CO 2 diffusion rate in the coal matrix is closely related to the higher adsorption energy and smaller kinetic diameter of CO 2 over CH 4 …”

Section: Resultsmentioning

confidence: 99%

“…It is known that apparent diffusivity through the nanopore structure is influenced by intrinsic properties, such as the coal rank and macrolithotype, , and external factors, such as the gas type and moisture. , At the initial pressure stage (<2.5 MPa), Knudsen diffusion plays a critical role in the mesopore range, and the predominance of Knudsen diffusion enhances the influence of the coal pore morphology on the whole diffusion process . However, the transition from mesopore to micropore decreases the bulk diffusion and strengthens the surface diffusion . Therefore, diffusion of gases in the coal matrix closely correlates to the coal pore morphology.…”

Section: Introductionmentioning

confidence: 99%

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Effects of Sub- and Supercritical CO₂ on Coal Diffusivity and Surface Thermodynamics

et al. 2022

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The diffusion mechanism of CH4 and CO2 on the coal matrix is fundamentally important for enhanced coal seam gas recovery and long-term CO2 sequestration in coal reservoirs. To investigate the influence of different-phase CO2 on the gas mass transfer and surface thermodynamics in the coal matrix, high volatile bituminous coal samples were prepared and treated with subcritical CO2 (SbCO2; 5 MPa and 318 K) and supercritical CO2 (ScCO2; 10 and 15 MPa, 318 K). The bidisperse model is used for sorption kinetics analysis. The results show that both effective macropore and micropore diffusivities of coal decreased after SbCO2 treatment but increased after ScCO2 treatment. The CO2 exposure pressure has a significant influence on sorption kinetics. A positive correlation existed between the effective micropore diffusivity and micropore surface area, demonstrating that the slow diffusion stage is dominated by surface diffusion in the micropores. In addition, micropore diffusion selectivity of coal multiplied after 10 MPa ScCO2 treatment. The standard enthalpy of adsorption increased with the CO2 pressure, enhancing the adsorption energy. The enhanced adsorption energy further hinders the gas mass transfer on the adsorbent surface.

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“…Immiscible fluid displacement path, controlled by the fluid viscosity ratio and capillary numbers, has significant influences on the efficiencies in the oil recovery and reservoir development. Over the past decade, much effort has been made to study the immiscible displacement paths and control factors of tight oil reservoirs using simulation and experimental methods. − In particular, many pore-scale studies have indicated that the transfer across the fluid–fluid interface is primarily controlled by the relative magnitude of viscous stress and capillary force. − Lenormand et al first investigated the effect of the competition of capillary forces and viscous stress on immiscible displacement fluid paths in two-dimensional micromodels. Capillary number ( Ca ), which is a function of the displacement speed, contact angle, and viscosity ratio, can characterize the effect of these forces on immiscible displacement processes.…”

Section: Introductionmentioning

confidence: 99%

Control of Generalized Capillary Number on Immiscible Displacement Path: NMR Online and Network Simulation of Fluid Displacement Mechanism

Zhao

et al. 2021

Energy Fuels

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Tight sandstone has a complex pore-throat structure and usually has multiple immiscible displacement paths. Capillary number may control and affect this process, but its control mechanism is still unclear. Therefore, this work aims to study the control process of generalized capillary number on the immiscible displacement process of tight sandstone. Through nuclear magnetic resonance (NMR) online experiments, real-time monitoring of changes in remaining oil in different-radius pores was performed under the control of different generalized capillary numbers. Combined with the microscopic experimental results of a scanning electron microscope and thin-section and constant-speed mercury intrusion, the pore-throat distribution law was obtained, and a pore network model based on a real core was established. The results show that under the control of low capillary numbers, the immiscible displacement path shifts to large and medium pores, while under the control of medium and high capillary numbers, the displacement path shifts to medium and small pores. Moreover, the simulation results also showed interesting phenomena that were not realized in the experiment. When the number of capillaries increases to a certain value (Ca ≈ 6.734 × 10–2 in this study area), unfavorable viscous displacement will occur in tight sandstones, that is, the displacement efficiency will decrease rapidly.

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Evaluation of surface diffusion in microporous/mesoporous media using a numerical model applied to rate-of-adsorption data: Implications for improved gas permeability estimation in shales/tight rocks using drill cuttings

Cited by 17 publications

References 82 publications

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

Effects of Sub- and Supercritical CO₂ on Coal Diffusivity and Surface Thermodynamics

Control of Generalized Capillary Number on Immiscible Displacement Path: NMR Online and Network Simulation of Fluid Displacement Mechanism

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Evaluation of surface diffusion in microporous/mesoporous media using a numerical model applied to rate-of-adsorption data: Implications for improved gas permeability estimation in shales/tight rocks using drill cuttings

Cited by 17 publications

References 82 publications

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

Huff-n-Puff Technology for Enhanced Oil Recovery in Shale/Tight Oil Reservoirs: Progress, Gaps, and Perspectives

Effects of Sub- and Supercritical CO2 on Coal Diffusivity and Surface Thermodynamics

Control of Generalized Capillary Number on Immiscible Displacement Path: NMR Online and Network Simulation of Fluid Displacement Mechanism

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Product

Resources

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Effects of Sub- and Supercritical CO₂ on Coal Diffusivity and Surface Thermodynamics