Gas sorption and non-Darcy flow in shale reservoirs

Wang, Xiukun; Sheng, James J.

doi:10.1007/s12182-017-0180-3

Cited by 31 publications

(10 citation statements)

References 32 publications

(51 reference statements)

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“…Sorption and desorption of gas is one of the most important issues in shale gas development (Wang et al 2018a, b;Xiong et al 2017). A lot of simulation and macroscopic adsorption experiments have been conducted about this issue, and clay minerals, total organic carbon content, organic matter maturity, and kerogen type are considered as the main factors affecting gas storage capacity (Jodłowski et al 2007;Wang et al 2019, Wang andSheng 2017;Zhang et al 2012. However, there are few studies on shale adhesion characteristics that control the release of oil and gas at microscopic scales, especially in nanopores.…”

Section: Discussionmentioning

confidence: 99%

Effect of dilute acid treatment on adhesion properties of Longmaxi black shale

et al. 2019

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Properties of shale in an acid environment are important when acid or CO 2 is injected into geologic formations as a working fluid for enhanced oil and gas recovery, hydraulic fracturing and reduced fracture initiation pressure. It has previously been shown that acid fluids can enhance the formation conductivity and decrease the hardness of shale. However, less is known about the effect of dilute acid on the adhesion properties of shale. In the study, shale samples are characterized in detail with advanced analysis. Adhesion properties of shale via dilute acid treatment were revealed by atomic force microscopy (AFM) for the first time. Results indicate that acid treatment can greatly enhance adhesion forces of the shale surface. After acid treatment, the average adhesion forces show a platform-like growth with an increase in loading force. Through analysis of results from AFM, scanning electron microscopy, and X-ray diffraction, we affirm that the enhanced adhesion forces are mainly from increased specific surface area and reduced elastic modulus. The results presented in this work help understand the adhesion properties of shale oil/gas present in an acidic environment, which have great significance in unconventional resources development.

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Section: Discussionmentioning

confidence: 99%

Effect of dilute acid treatment on adhesion properties of Longmaxi black shale

et al. 2019

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“…For instance, CBM occurs mainly in an absorbed/adsorbed state. For shale gas, the free, absorbed/adsorbed and dissolved states are significant, but the ratio among them is variable (Curtis 2002;Wang and Sheng 2017). According to Jarvie (2012), the proportion of absorbed/adsorbed gas in the major shale gas accumulations of North America is 10%-70%, and that of free gas accounts for 30%-90%.…”

Section: Source-rock Petroleum System (Sps)mentioning

confidence: 99%

The petroleum system: a new classification scheme based on reservoir qualities

Zhao

et al. 2018

Pet. Sci.

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A new classification of petroleum systems (PSs) based on reservoir qualities is proposed. We classify PSs into the following three basic types: (1) source-rock petroleum system (SPS); (2) tight-reservoir or tight petroleum system (TPS); and (3) conventional-reservoir or conventional petroleum system (CPS). The CPS is a PS in which hydrocarbons accumulate in conventional reservoirs, and all the essential elements and processes are significant and indispensable. Oil and gas accumulations are geographically discrete and therefore exist as discontinuous accumulations. The TPS is a PS where hydrocarbons accumulate in tight reservoirs and the source rock, reservoir, seal, migration, and trap are also indispensable, but the traps are mostly non-anticlinal and the accumulations are primarily quasi-continuous and secondarily discontinuous. The SPS is a PS where both hydrocarbon generation and accumulation occurred in source rocks and traps and migration are unnecessary or inconsequential; the hydrocarbon distribution is extensive and continuous and has no distinct boundaries. The aforementioned three PSs can be derived from a common hydrocarbon source kitchen and are closely linked in terms of their formation and distribution. Therefore, to maximize the exploration efficiency, a comprehensive study and different strategies are needed by considering the SPS, TPS, and CPS as parts of a greater whole.

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“…Shale gas deposits in a reservoir with multiple storage mechanisms, including dissolved gas, free gas, and adsorbed gas. [ 44,45 ] Dissolved gas refers to the gas dissolved in kerogen. Compared with the other two, the amount of dissolved gas is much lower, and its contribution to gas flow can be ignored.…”

Section: Introductionmentioning

confidence: 99%

A comprehensive review on the flow behaviour in shale gas reservoirs: Multi‐scale, multi‐phase, and multi‐physics

Feng

Chen

et al. 2022

Can J Chem Eng

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An accurate description of fluid flow is critical for the prediction of the productivity of shale gas reservoirs. In this paper, we present the current advances and a systematic summary on the fluid flow in shale gas reservoirs. First, shale pore structures, consisting of organic pores and inorganic pores ranging from nanoscale to micro-scale, and reservoir fluids, including free gas, absorbed gas, and water, are systematically presented. Thereafter, multi-physics flow phenomena motivated by scale effects, such as continuum flow, slip flow, transition flow, free molecular flow, and surface diffusion for gas, as well as the effective viscosity and slip boundary condition for water, are carefully summarized. Meanwhile, these flow mechanisms are discussed with molecular dynamics (MD) simulations and theoretical analysis. Subsequently, on the basis of upscaling approaches, including capillary bundle models, the lattice Boltzmann method (LBM), and pore network models (PNMs), fluid flow through heterogeneous shale matrix is reviewed and the influences of scale effects and pore structures are clarified. Additionally, shale gas well performance is discussed by combining the multiple transport mechanisms and a fracturing-shut-in-flowback-production process. Our review concluded that the fluid flow behaviour in shale gas reservoirs is a complex multi-scale process accompanied by multi-physical phenomena and multi-fluid distributions. Keeping this in mind is helpful for predicting the shale gas production and recoverable gas resources. We expect this study can not only help by providing a better understanding of the fluid flow in shale reservoirs but also provide significant implications to address other multiphase flow processes.

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Gas sorption and non-Darcy flow in shale reservoirs

Cited by 31 publications

References 32 publications

Effect of dilute acid treatment on adhesion properties of Longmaxi black shale

Effect of dilute acid treatment on adhesion properties of Longmaxi black shale

The petroleum system: a new classification scheme based on reservoir qualities

A comprehensive review on the flow behaviour in shale gas reservoirs: Multi‐scale, multi‐phase, and multi‐physics

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