Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

Yang, Yuxuan; Wang, Sen; Feng, Qihong; Cao, Xuewen; Qin, Yong; Shu, Chenglong; Anhai, Zhong; Wang, Xuewu

doi:10.1021/acs.energyfuels.3c00502

Cited by 15 publications

(5 citation statements)

References 147 publications

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“…For deep CBM, the multiscale research method of shale reservoirs can be learned in the future. , The gas adsorption characteristics and imbibition mechanisms of deep coal rock reservoirs can be studied from the molecular scale and nanoscale so as to find a way to effectively improve the recovery rate of deep CBM.…”

Section: Differences In Production Characteristics Of Deep Cbm Wellsmentioning

confidence: 99%

Dynamic Production Characteristics of Deep Coalbed Methane: A Case Study of Daning-Jixian Block

Zhang,

Lai,

Meng

et al. 2024

Energy Fuels

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The Daning-Jixian block, located in the eastern margin of the Ordos Basin, is abundant in deep coalbed methane (CBM) resources and serves as a pilot test block for deep CBM development in China. Currently, the exploration and development of a deep CBM are in the early stages. The production characteristics and development laws across different production stages are not fully elucidated, leading to uncertainties in discharge and production control measures as well as the optimization of the production system. This study addresses these challenges by analyzing actual production data from deep CBM wells. It establishes a classification standard for deep CBM wells and a production stage model diagram. Based on this, it compares and analyzes the production characteristics of deep CBM wells with middle and shallow CBM wells as well as the variations among different types of deep CBM wells. The findings reveal the following key points: (1) gas wells are categorized as low-, medium-and high-production wells based on average daily gas production of 1500 and 3000 m 3 /d, respectively; (2) deep CBM production is delineated into four stages: gas production rise, gas production decline, stable gas production, and gas production depletion; (3) in contrast to middle and shallow CBM wells, deep CBM wells predominantly produce free gas in the early stage, characterized by rapid and high gas production; and (4) the production capacity of deep CBM wells is mainly influenced by reservoir stress characteristics, the effectiveness of fracturing, and the continuity of production. This study provides a valuable reference for the formulation of deep CBM drainage and production systems and development strategies.

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Section: Differences In Production Characteristics Of Deep Cbm Wellsmentioning

confidence: 99%

Dynamic Production Characteristics of Deep Coalbed Methane: A Case Study of Daning-Jixian Block

Zhang,

Lai,

Meng

et al. 2024

Energy Fuels

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“…[5][6][7][8][9][10]12,22,23 The essence of shale oil and gas is the residual hydrocarbons in shale. 7,24 The generation, residue, and discharge of hydrocarbons in shales are controlled by their maturity, leading to significant differences in oil and gas properties in shales with different maturities. 6−9 Vitrinite reflectance (R o ) values of 0.9 and 1.0% have been regarded as the critical conditions of medium-low and medium-high maturity in the in-depth exploration of shale oil and gas, respectively.…”

Section: Introductionmentioning

confidence: 99%

“…The essence of shale oil and gas is the residual hydrocarbons in shale. , The generation, residue, and discharge of hydrocarbons in shales are controlled by their maturity, leading to significant differences in oil and gas properties in shales with different maturities. − Vitrinite reflectance ( R o ) values of 0.9 and 1.0% have been regarded as the critical conditions of medium-low and medium-high maturity in the in-depth exploration of shale oil and gas, respectively. ,− ,, The medium- and high-maturity shales have a high retained hydrocarbon content, with a high gas–oil ratio, low viscosity, and good fluidity. The hydrocarbons mainly remain in inorganic pores and abundant organic pores in the gaseous state. , The middle-low-maturity shales are enriched in organic matter, with a low hydrocarbon conversion rate.…”

Section: Introductionmentioning

confidence: 99%

Differences between the Hydrocarbon-Bearing Properties of Shales with Differing Maturities: Shahejie and Longmaxi Shales

Chen,

Huang,

Jiang

et al. 2024

Energy Fuels

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In order to better understand hydrocarbon enrichment in shales with various thermal maturities, we experimentally evaluate the geological characteristics of shales in the Third Member of the Shahejie Formation of the Bohai Bay Basin and draw comparisons with the Longmaxi shales in the Sichuan Basin. The kerogens in the Third Member and in the Longmaxi shales are mainly similar of types I and II and occur dominantly in micro-and nanopores. A difference in maturity results in significant differences in shale compositions, pore structure, and hydrocarbon enrichment characteristics. The Third Member shale contains a large proportion of high TOC material, and mesopores are dominant. The Longmaxi shales contain a large proportion of low TOC material, and nanoscale pores such as organic pores are common; the Longmaxi shales are also more brittle. The nanopores in medium-to high-mature Longmaxi shales have a large specific surface area, the high adsorption capacity of which clearly controls the accumulation and fluidity of hydrocarbons. Micromigration and accumulation of hydrocarbons in interlayers of middle-low-maturity shales are affected by pore structure and overpressure as well as by fault activity.

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“…Cao et al found that the smaller the ratio of oil viscosity to water viscosity, the better the dynamic imbibition effect. The higher the initial water saturation, the worse the dynamic imbibition effect [40][41][42][43]. Based on the CT online experimental system, Yang et al explored the influence of pressure, permeability, and initial water saturation on imbibition distance according to changes in core water saturation during imbibition [44].…”

Section: Introductionmentioning

confidence: 99%

Investigating the Influencing Factors of Imbibition of Fracturing Fluids in Tight Reservoirs

Liu,

Qu,

Wang

et al. 2024

Processes

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Tight reservoirs are the focus of unconventional oil and gas resource development, but most tight reservoirs exhibit complex pore structures, strong non-homogeneity, and limited water drive development. Fracturing fluid imbibition is a critically important way to improve the recovery of tight reservoirs. In this paper, an NMR experimental device was used to conduct imbibition experiments in tight reservoirs, and the relationship between temperature, pressure, matrix permeability, and imbibition recovery was investigated. Based on the fracturing fluid imbibition recovery curve, the imbibition process is divided into the fast imbibition stage, slow imbibition stage, and imbibition equilibrium. In addition, based on the pore structure division, the recovery changes of each pore under different experimental conditions were quantitatively analyzed. The results indicate that the highest imbibition recovery is achieved at an experimental pressure of 5 MPa within the range of 0 MPa to 15 MPa. Increasing the experimental pressure can increase the imbibition rate but will not increase imbibition recovery. Within the investigated range in this paper, fracturing fluid imbibition increases with rising temperature and matrix permeability. Moreover, the recovery of each pore gradually increases with the experimental pressure ranging from 0 MPa to 5 MPa. The recovery of each pore is positively correlated with matrix permeability and temperature. During the experiment, micropores contributed the most to the recovery, while macropores contributed the least. The study in this paper guides the efficient development of tight reservoirs.

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Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

Cited by 15 publications

References 147 publications

Dynamic Production Characteristics of Deep Coalbed Methane: A Case Study of Daning-Jixian Block

Dynamic Production Characteristics of Deep Coalbed Methane: A Case Study of Daning-Jixian Block

Differences between the Hydrocarbon-Bearing Properties of Shales with Differing Maturities: Shahejie and Longmaxi Shales

Investigating the Influencing Factors of Imbibition of Fracturing Fluids in Tight Reservoirs

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