The role of osmotic effects in fluid flow through shales

Lomba, R.F.T.; Chenevert, Martin E.; Sharma, Mukul M.

doi:10.1016/s0920-4105(99)00029-7

Cited by 75 publications

(33 citation statements)

References 4 publications

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“…We couple fluid and heat flow to non-isothermal chemical-potential equilibrium and geomechanics by solving Equations (10) and (16) (17), (21), (24), (27), (29) and (32)) from the fluid and heat flow formulation in hydraulic fractures, natural fractures and matrix. The fluid and heat flow, chemical-potential equilibrium and geomechanical equations are discretized in space using the finite-difference method.…”

Section: Coupling and Solution Of Simulator Equationsmentioning

confidence: 99%

“…However, the salinity of slickwater fracturing-fluids is low, approximately 1000 ppm [25,26]. Chemical osmosis occurs in the leak-off process of hydraulic fracturing (because two conditions are satisfied for the occurrence of chemical osmosis, i.e., clay semipermeable membrane and salinity difference on both sides of the membrane), which results in the transport of water molecules from the low-salinity side to the high-salinity side until the salt concentration reaches an equilibrium on both sides of the shale membrane [26][27][28][29]. That makes chemical osmosis a possible leak-off mechanism for the invasion of water-based fracturing-fluids in fractured shale [30][31][32].…”

Section: Introductionmentioning

confidence: 99%

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Coupled Thermo-Hydro-Mechanical-Chemical Modeling of Water Leak-Off Process during Hydraulic Fracturing in Shale Gas Reservoirs

Wang

Zhang

2017

Energies

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Abstract:The water leak-off during hydraulic fracturing in shale gas reservoirs is a complicated transport behavior involving thermal (T), hydrodynamic (H), mechanical (M) and chemical (C) processes. Although many leak-off models have been published, none of the models fully coupled the transient fluid flow modeling with heat transfer, chemical-potential equilibrium and natural-fracture dilation phenomena. In this paper, a coupled thermo-hydro-mechanical-chemical (THMC) model based on non-equilibrium thermodynamics, hydrodynamics, thermo-poroelastic rock mechanics, and non-isothermal chemical-potential equations is presented to simulate the water leak-off process in shale gas reservoirs. The THMC model takes into account a triple-porosity medium, which includes hydraulic fractures, natural fractures and shale matrix. The leak-off simulation with the THMC model involves all the important processes in this triple-porosity medium, including: (1) water transport driven by hydraulic, capillary, chemical and thermal osmotic convections; (2) gas transport induced by both hydraulic pressure driven convection and adsorption; (3) heat transport driven by thermal convection and conduction; and (4) natural-fracture dilation considered as a thermo-poroelastic rock deformation. The fluid and heat transport, coupled with rock deformation, are described by a set of partial differential equations resulting from the conservation of mass, momentum, and energy. The semi-implicit finite-difference algorithm is proposed to solve these equations. The evolution of pressure, temperature, saturation and salinity profiles of hydraulic fractures, natural fractures and matrix is calculated, revealing the multi-field coupled water leak-off process in shale gas reservoirs. The influences of hydraulic pressure, natural-fracture dilation, chemical osmosis and thermal osmosis on water leak-off are investigated. Results from this study are expected to provide a better understanding of the predominant leak-off mechanisms for slickwater fracturing-fluids in hydraulically fractured shale gas reservoirs.

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Section: Coupling and Solution Of Simulator Equationsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Coupled Thermo-Hydro-Mechanical-Chemical Modeling of Water Leak-Off Process during Hydraulic Fracturing in Shale Gas Reservoirs

Wang

Zhang

2017

Energies

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“…The chemical imbalance between the drilling fluid and shale formation is usually expressed in terms of the solute concentration of the aqueous fluid [16,17]. However, there are various types of chemical reactions that affect the concentration of solute during transport in porous media, such as cation exchange and sorption phenomena [49].…”

Section: A Diffusion-sorption Modelmentioning

confidence: 99%

“…(15) and (16) into Eqs. (17)(18)(19). The resulting formulation is solved using the specified boundary conditions.…”

Section: Wellbore Stability Modelingmentioning

confidence: 99%

Effects of Sorptive Tendency of Shale on Borehole Stability

Dokhani¹,

Yu²

2016

JGRE

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Abstract:Interactions between aqueous drilling fluids and clay minerals have been identified as an important factor in wellbore instability of shale formations. Current wellbore stability models consider the interactions between aqueous drilling fluids and pore fluid but the interactions with shale matrix are neglected. This study provides a realistic method to incorporate the interaction mechanism into wellbore stability analysis through laboratory experiment and mathematical modeling. The adsorption isotherms of two shale rocks, Catoosa Shale and Mancos Shale are obtained. The adsorption isotherms of the selected shales are compared with those of other shale types in the literature. This study shows that the adsorption theory can be used to generalize wellbore stability problem in order to consider the case of non-ideal drilling fluids. Furthermore, the adsorption model can be combined with empirical correlations to update the compressive strength of shale under downhole conditions. Accordingly, a chemo-poro-elastic wellbore stability simulator is developed to explore the stability of transversely isotropic shale formations. The coupled transport equations are solved using an implicit finite difference method. The results of this study indicate that the range of safe mud weight reduces due to the moisture adsorption phenomenon.

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“…They interact with the drilling fluid, experience failure, and produce excessive solids to be removed from the well and from an enlarged borehole in which it is difficult to work (Lomba et al, 2000). Consequently, typical problems such as bit-balling, disintegration of cuttings, borehole wash-out, high torque and drag, and stuck pipes are often encountered as a result of water adsorption by water-sensitive shales (Steiger & Leung, 1992).…”

Section: Introductionmentioning

confidence: 99%

The Influence of Chemical Additives in Filtration Control of Inhibited Drilling Fluids

Dantas

Leite

Nascimento

et al. 2014

BJPG

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This work evaluates the influence of chemical additives, namely, starch, high-viscosity carboxymethylcellulose (HV-CMC), and calcite on rheological and filtration properties of inhibited drilling fluids composed by potassium citrate. A total of 11 experiments were conducted using a 2 3 -factorial design, three of which were in the central point. The concentration of starch varied from 0 to 0.0343 kg/L, the concentration of HV-CMC ranged between 0 and 0.0043 kg/L, and the concentration of calcite from 0 to 0.071 kg/L. Rheological and filtration properties were determined for the studied fluids. According to the results, starch and HV-CMC influence statistically the rheological properties of the studied fluids. The filtration properties, on the other hand, are statistically affected by these additives. The best results for fluid loss were obtained with fluids comprising starch and calcite in high concentrations, or with starch, HV-CMC, and calcite in high concentrations.

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The role of osmotic effects in fluid flow through shales

Cited by 75 publications

References 4 publications

Coupled Thermo-Hydro-Mechanical-Chemical Modeling of Water Leak-Off Process during Hydraulic Fracturing in Shale Gas Reservoirs

Coupled Thermo-Hydro-Mechanical-Chemical Modeling of Water Leak-Off Process during Hydraulic Fracturing in Shale Gas Reservoirs

Effects of Sorptive Tendency of Shale on Borehole Stability

The Influence of Chemical Additives in Filtration Control of Inhibited Drilling Fluids

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