Experimental study of spontaneous imbibition for oil recovery in tight sandstone cores under high pressure high temperature with low field nuclear magnetic resonance

Guo, Xiao; Semnani, Amir; Ekekeh, Destina Godwin; Gao, Zhendong; Ostadhassan, Mehdi; Jia, Haowei; Fu, Jing; Wang, Ying

doi:10.1016/j.petrol.2021.108366

Cited by 14 publications

(6 citation statements)

References 31 publications

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“…However, if salinity is a controlling factor, then it can prevent the swelling of minerals and limit the amount of water intake [ 40 ]. Compared to ambient conditions, thermodynamic factors influence the reaction, at high temperature high pressure conditions result in higher imbibition efficiency [ 41 ]. Likewise, carbonate cement exhibiting etched outlines reveals the dissolution process, and formation of secondary porosity and leading to pore bridging and network expansion [ 42 ].…”

Section: Discussionmentioning

confidence: 99%

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Miletić,

Küçükuysal,

Gülcan

et al. 2024

Heliyon

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Section: Discussionmentioning

confidence: 99%

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Miletić,

Küçükuysal,

Gülcan

et al. 2024

Heliyon

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“…This shifts to spontaneous imbibition as the fracture and reservoir pressures equilibrate. − Research by Takahashi and Kovscek, which involved experimental simulations measuring interfacial tension, concluded that the final recovery rate in spontaneous imbibition is governed by the interplay between capillary pressure and saturation. Studies by Makhanov et al on the influence of rock textures on water-phase imbibition in shale revealed higher imbibition rates and volumes in samples oriented parallel to bedding planes compared to those oriented perpendicular. − …”

Section: Introductionmentioning

confidence: 98%

Quantitative Analysis of Crude Oil Mobilization in Microscopic Pores during the Spontaneous Imbibition of CO₂-Enhanced Fracturing Fluids in Shale Oil Reservoirs

Li,

Yan,

Wang

et al. 2024

Energy Fuels

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Spontaneous imbibition is integral to various critical phases of shale oil reservoir development, including volume fracturing and water injection, profoundly influencing oil production. Understanding the dynamics of shale imbibition and its influencing factors is essential for optimizing shale oil reservoir recovery rates. This study investigated the behavior of crude oil within microscopic pores during the spontaneous imbibition of fracturing fluids, examining the impacts of shale mineral texture, imbibition techniques, and other relevant variables. Conducted on rock cores from the Chang 7 Member in the Ordos Basin, China, the experiments aimed to decipher the mechanisms by which reservoir physical properties and pore structures influence the spontaneous imbibition of fracturing fluids in shale oil reservoirs. The study also integrated nuclear magnetic resonance (NMR) technology, analyzing alterations in the NMR T 2 spectrum during imbibition. This approach facilitated a detailed study of crude oil mobilization across microscopic pores of varying diameters, enabling a thorough quantitative assessment of oil recovery from diverse pore structures. Experiments were conducted on five core samples using two different formulations of fracturing fluids: the CNI nano variable-viscosity slick water-based fracturing fluid and the EM30 + + guar gum water-based fracturing fluid. The effects of these fracturing fluids on oil displacement were assessed. Findings indicate that smaller pores in shale reservoirs predominantly facilitate crude oil mobilization during the spontaneous imbibition of fracturing fluids with significant activity in the initial stages. Variations in the pore structures of different cores substantially affect the crude oil mobility and displacement rates during the spontaneous imbibition of fracturing fluids. The disparity in pore structures emerges as a principal factor dictating the extent of crude oil mobilization during the spontaneous imbibition of fracturing fluids in shale reservoirs. Moreover, the imbibition capacity is influenced by a range of factors, including rock wettability, reservoir quality, and physical properties.

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“…This dominance can be attributed to the limitations of conventional laboratory flow experimental methods, which involve fluid displacement through core grippers and face challenges due to the extremely low permeability of shale cores. Oilfield development practice has demonstrated that utilizing the imbibition absorption effect of capillary pressure in combination with differential pressure drive helps to improve the development effect [29]. Consequently, the effective exertion of the imbibition absorption and driving effect between matrix and fracture and the increase in the degree of matrix mobilization based on the consideration of matrix and fracture coupled reservoir characteristics has become the key to improving the development effect of shale oil.…”

Section: Introductionmentioning

confidence: 99%

Flow Characterization in Fractured Shale Oil Matrices Using Advanced Nuclear Magnetic Resonance Techniques

Li,

Sun,

Gao

et al. 2024

Processes

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The evaluation of flow dynamics in fractured shale oil reservoirs presents significant challenges due to the complex pore configurations and high organic material concentration. Conventional methods for petrophysical and fluid dynamic evaluations are insufficient in addressing these complexities. However, nuclear magnetic resonance (NMR) technology is an effective technique for quantitatively delineating fluid micro-transport properties across the reservoir core. This study presents an experimental methodology rooted in NMR technology to quantify the flow capabilities within the shale oil matrix. This approach incorporates high-pressure saturation flow experiments across seven distinct core samples to gauge the micro-transport phenomena of fluids across various pore dimensions. The results revealed that under high-pressure saturation, shale cores devoid of fractures demonstrated an average crude oil saturation rate of merely 19.44%. Cores with evident stratification exhibited a 16.18% increase in flow capacity compared to their non-stratified counterparts. The flow dynamics within these shale reservoirs exhibited a range of behaviors, from non-linear to linear. In lower-permeability zones, non-linear patterns became increasingly apparent. An NMR T2 spectrum analysis was used to identify the minimum effective pore size conducive to shale oil flow within the matrix, which was between 8 and 10 nanometers. These insights provide a foundation for a deeper understanding of the mechanisms behind oil and gas migration in fractured shale oil matrices, offering valuable insight into their extractive potential.

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Experimental study of spontaneous imbibition for oil recovery in tight sandstone cores under high pressure high temperature with low field nuclear magnetic resonance

Cited by 14 publications

References 31 publications

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Quantitative Analysis of Crude Oil Mobilization in Microscopic Pores during the Spontaneous Imbibition of CO₂-Enhanced Fracturing Fluids in Shale Oil Reservoirs

Flow Characterization in Fractured Shale Oil Matrices Using Advanced Nuclear Magnetic Resonance Techniques

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Experimental study of spontaneous imbibition for oil recovery in tight sandstone cores under high pressure high temperature with low field nuclear magnetic resonance

Cited by 14 publications

References 31 publications

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Imaging porosity evolution of tight sandstone during spontaneous water imbibition by X-ray Micro-CT

Quantitative Analysis of Crude Oil Mobilization in Microscopic Pores during the Spontaneous Imbibition of CO2-Enhanced Fracturing Fluids in Shale Oil Reservoirs

Flow Characterization in Fractured Shale Oil Matrices Using Advanced Nuclear Magnetic Resonance Techniques

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Quantitative Analysis of Crude Oil Mobilization in Microscopic Pores during the Spontaneous Imbibition of CO₂-Enhanced Fracturing Fluids in Shale Oil Reservoirs