Current understanding of shale wettability: A review on contact angle measurements

Siddiqui, Mohammed Abdul Qadeer; Ali, S.M. Farouq; Fei, Haoxiang; Roshan, Hamid

doi:10.1016/j.earscirev.2018.04.002

Cited by 182 publications

(123 citation statements)

References 44 publications

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“…Phyllosilicate kaolinite is composed of a single tetrahedral silicon‐oxygen (siloxane) and an octahedral aluminum‐oxygen (gibbsite) sheets. Several studies have been conducted to investigate the wettability of water/oil droplets on kaolinite surfaces (Papavasileiou et al, ; Siddiqui et al, ; Zhang et al, ). Šolc et al () conducted molecular dynamics simulations to study the wettability of the basal kaolinite.…”

Section: Resultsmentioning

confidence: 99%

Wetting Behavior of Tight Rocks: From Core Scale to Pore Scale

Habibi

Dehghanpour

2018

Water Resources Research

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Previous measurements show mixed‐wet behavior of tight siltstone core plugs, initially saturated with air. However, the same plugs show water‐wet behavior when saturated with oil or water. This study aims at explaining these observations by investigating the effects of mineral heterogeneity and intermolecular forces acting on solid/liquid and liquid/liquid interfaces. First, we conduct pore‐scale visualizations to characterize the minerals surrounding the pores of the tight rock samples. Thin‐section and scanning electron microscopy/energy dispersive X‐ray spectroscopy analyses show the existence of multimineral pores, which can be responsible for the mixed‐wet behavior. Next, we apply the DLVO theory to investigate the intermolecular forces acting on solid/liquid and liquid/liquid interfaces. We use disjoining pressure‐distance profiles and contact angles calculated for different minerals to evaluate the stability of the thin film covering the rock grains and to explain the wettability of the core plugs during spontaneous imbibition tests. The disjoining pressure values calculated for the dry core plugs suggest similar wetting affinities toward oil and water. However, the contact angles calculated for the water‐saturated core plugs suggest the water‐wet behavior, which agrees with the countercurrent imbibition results. Finally, we measure the adhesion forces between the tip of a cantilever and (1) pure quartz slide, (2) pure calcite crystal, and (3) the rock thin section using an atomic force microscope. The values of adhesion forces measured for the thin section composed of multimineral pores are between those measured for pure quartz slide and pure calcite crystal.

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Section: Resultsmentioning

confidence: 99%

Wetting Behavior of Tight Rocks: From Core Scale to Pore Scale

Habibi

Dehghanpour

2018

Water Resources Research

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“…Many studies have focused on the factors influencing spontaneous imbibition in shale (Nelson, 2009;Dehghanpour et al, 2012;Xu and Dehghanpour, 2014;Singh, 2016;Zhou et al, 2016;Javaheri et al, 2017;Siddiqui et al, 2018), including capillarity in organic and inorganic pore network systems, initial and induced fractures caused by liquid-clay mineral interactions, pore structure (pore size distribution) and microstructure (roughness, tortuosity and connectivity), wettability, osmotic forces, mineral contents, liquid-flowing behavior, and physical and electrochemical interactions between liquid and shale. Instead of reviewing studies on the basis of factors influencing liquid uptake by shale, the review in this section focuses on progress in laboratory methods and techniques to observe spontaneous imbibition.…”

Section: Experimental Progress In Laboratory Methods For Observation mentioning

confidence: 99%

Spontaneous imbibition in shale: A review of recent advances

Singh

Cai

2019

Capillarity

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Spontaneous imbibition in shale is commonly observed during and after hydraulic fracturing. This mechanism greatly influences hydrocarbon recovery in shale plays, therefore attracting increasing attention from researchers. The number of related publications is increasing. In this review, we summarize the recent advances in shale spontaneous imbibition from three aspects, namely, conventional spontaneous imbibition models, common experimental methods, and key mechanisms that need to be focused on. The major influencing factors on the shale imbibition process are discussed, and promising future works are presented on the basis of the merits and demerits of the recent studies. This study discusses the mechanisms of shale-liquid interaction, the complexity of multiphase flow in shale plays, and highlights the achievements and challenges in shale imbibition research.

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“…To obtain the capillary curve, the capillary force at any given radius is firstly calculated according to the Young-Laplace equation (Equation (11)). The surface tension used here is 0.072 Pa•m, and θ is assumed to be 0 in this study due to the relatively high quartz content [40,41]. Then, the corresponding water saturation can be calculated by the method mentioned in Section 2.3.…”

Section: Geofluidsmentioning

confidence: 99%

Parameter Prediction of Water Imbibition in Unsaturated Shales Using the NMR Method

et al. 2019

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Although the hydraulic fracturing treatment can improve the conductivity of shale reservoirs, the low recovery rate of the fracturing fluid may cause potential environmental and production issues. For an accurate investigation of these issues, an appropriate model of the water imbibition in shales is required. However, the hydraulic parameters related to water imbibition in shales are hard to be measured due to their tiny pores. In this study, an effective method is proposed to estimate the water imbibition volume. The nuclear magnetic resonance method is applied to obtain the related parameters including the capillary curve, the intrinsic and relative permeability of the shale, which can significantly cut down the time and cost needed to get these data. This model is validated by water imbibition experiments. In addition, we compare two empirical equations used to calculate intrinsic permeability in the NMR method and calibrate the corresponding parameter a for shale, which is poorly investigated in literature. Finally, we suggest that the capillary force dominates the early stage of water imbibition process in unsaturated shales, and the late period may be influenced more by other mechanisms such as the osmosis and the surface hydration.

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Current understanding of shale wettability: A review on contact angle measurements

Cited by 182 publications

References 44 publications

Wetting Behavior of Tight Rocks: From Core Scale to Pore Scale

Wetting Behavior of Tight Rocks: From Core Scale to Pore Scale

Spontaneous imbibition in shale: A review of recent advances

Parameter Prediction of Water Imbibition in Unsaturated Shales Using the NMR Method

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