Quantitative characterization of shale pore connectivity and controlling factors using spontaneous imbibition combined with nuclear magnetic resonance T2 and T1-T2

Zhang, Pengfei; Lu, Shuangfang; Li, Junqian; Chang, Xiangchun; Zhang, Junjian; Pang, Yumao; Lin, Zizhi; Chen, Guo; Yin, Yajie; Liu, Yuqi

doi:10.1016/j.petsci.2023.03.011

Cited by 7 publications

(1 citation statement)

References 39 publications

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“…Expanding on the research by Xiao et al, Zhang et al determined effective porosity initiation times for two tight sandstones, recorded at 1 and 2.8 ms, respectively. Gao et al classified shale pores into three types: inorganic intergranular pores, inorganic intragranular pores, and organic pores. − …”

Section: Introductionmentioning

confidence: 99%

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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Section: Introductionmentioning

confidence: 99%

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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The occurrence of pore fluid in shale-oil reservoirs using nuclear magnetic resonance: The Paleogene Funing Formation, Subei Basin, Eastern China

Zhang,

Wu,

et al. 2024

Marine and Petroleum Geology

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Microscopic occurrence and distribution of oil and water in situ shale: Evidence from nuclear magnetic resonance

Zhang,

Lu,

Wang

et al. 2024

Petroleum Science

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Quantitative characterization of shale pore connectivity and controlling factors using spontaneous imbibition combined with nuclear magnetic resonance T2 and T1-T2

Cited by 7 publications

References 39 publications

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

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

The occurrence of pore fluid in shale-oil reservoirs using nuclear magnetic resonance: The Paleogene Funing Formation, Subei Basin, Eastern China

Microscopic occurrence and distribution of oil and water in situ shale: Evidence from nuclear magnetic resonance

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Quantitative characterization of shale pore connectivity and controlling factors using spontaneous imbibition combined with nuclear magnetic resonance T2 and T1-T2

Cited by 7 publications

References 39 publications

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

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

The occurrence of pore fluid in shale-oil reservoirs using nuclear magnetic resonance: The Paleogene Funing Formation, Subei Basin, Eastern China

Microscopic occurrence and distribution of oil and water in situ shale: Evidence from nuclear magnetic resonance

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Product

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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

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