Dynamic capillary effects in heterogeneous porous media

Helmig, Rainer; Weiss, André; Wohlmuth, Barbara

doi:10.1007/s10596-007-9050-1

Cited by 63 publications

(43 citation statements)

References 18 publications

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“…In the last decade, a number of studies have discussed the significance of dynamic capillary pressure and s in different circumstances. 7,[19][20][21]23,[25][26][27][28][29][30][31][32][33][34][35][36][37][38][39][40][41][42][43] For example, hysteretic dynamic effect in the capillary pressure relationship was discussed in a theoretical study by Beliaev and Hassanizadeh 19 . Hassanizadeh et al 20 interpreted the imbibition experiments (displacement of oil by water) of Kalaydjian 44 Pa s for MI, which imply that the dynamic coefficient was found to be higher for imbibition than that for drainage by Hassanizadeh et al 21 Another study which is relevant to the current article was conducted by Sakaki et al 23 Sakaki et al conducted PD, MD, and MI experiments and measured s values for these three cases for a single porous domain of saturated hydraulic conductivity 0.016 cm/s.…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of hysteretic dynamic effect in capillary pressure–saturation relationship for two‐phase flow in porous media

Mirzaei

Das

2013

AIChE Journal

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Well-defined laboratory experiments have been carried out to investigate hysteretic dynamic effect in capillary pressure-saturation relationships for two-phase flow in homogeneous and heterogeneous (layered) porous media. Conceptually, the dependence of the capillary pressure curves on the rate of change of saturation (dS w /dt) is defined as the dynamic effect in capillary pressure relationship, which is indicated by a dynamic coefficient, s (Pa s) and it determines the rate at which two-phase flow equilibrium is reached, i.e., dS w /dt 5 0 where S w and t are the water saturation and time, respectively. The dependences of s on various fluid and porous materials properties have been studied in the context of drainage; but, there is limited study for imbibition and the hysteresis of s2S w relationships. As such, the emphasis in this article is on reporting s2S w curves for imbibition while also demonstrating the hysteresis in the s2S w relationships by comparing s2S w curves for drainage (previously reported) and imbibition (this study) in carefully designed laboratory experiments. Homogeneous sand samples composed of either fine (small particle size and lower permeability) or coarse (larger particle size and higher permeability) sand have been used for these experiments. Furthermore, a layered domain made of a find sand layer sandwiched between two coarse sand layers is used as a model of heterogeneous domain. The results of the study confirm that the s2S w relationships are hysteretic in nature and, as such, the speed to flow equilibrium should vary depending on whether drainage or imbibition takes place. At a particular water saturation, the magnitudes of the dynamic coefficient (s) are found to be generally higher for imbibition, which imply that the speed to flow equilibrium at the same saturation will be slower for imbibition.

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Section: Introductionmentioning

confidence: 99%

Experimental investigation of hysteretic dynamic effect in capillary pressure–saturation relationship for two‐phase flow in porous media

Mirzaei

Das

2013

AIChE Journal

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“…All results refer to the case J (1) > 0, hence to the entry pressure model. If instead, J (1) = 0 (no entry pressure), s * = 1 and the analysis before leads to s − < 1, and p − (t) = p + (t) for all t > 0 (see Helmig et al 2007). …”

Section: Proposition 2 Assume Smentioning

confidence: 99%

“…The case of vanishing capillary effects and the connection to hyperbolic conservation laws is studied in Duijn et al ( , 2013. For dynamic capillarity models in the heterogeneous case, but in the absence of an entry pressure, numerical schemes are discussed in Helmig et al (2007). This situation is similar to the case analyzed in Cuesta and Pop (2009), where the interface is replaced by a discontinuity in the initial conditions.…”

Section: Introductionmentioning

confidence: 99%

Two-Phase Flow in Porous Media: Dynamic Capillarity and Heterogeneous Media

2015

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We investigate a two-phase porous media flow model, in which dynamic effects are taken into account in phase pressure difference. We consider a one-dimensional heterogeneous case, with two adjacent homogeneous blocks separated by an interface. The absolute permeability is assumed constant, but different in each block. This may lead to the entrapment of the non-wetting phase (say, oil) when flowing from the coarse material into the fine material. We derive the interface conditions coupling the models in each homogeneous block. In doing so, the interface is approximated by a thin porous layer, and its thickness is then passed to zero. Such results have been obtained earlier for standard models, based on equilibrium relationship between the capillary pressure and the saturation. Then, oil is trapped until its saturation on the coarse material side of the interface exceeds an entry value. In the non-equilibrium case, the situation is different. Due to the dynamic effects, oil may still flow into the fine material even after the saturation drops under the entry point, and this flow may continue for a certain amount of time that is proportional to the non-equilibrium effects. This suggests that operating in a dynamic regime reduces the account of oil trapped at interfaces, leading to an enhanced oil recovery. Finally, we present some numerical results supporting the theoretical findings.

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“…Therefore, the behavior of fluid in tight reservoir still awaits to be revealed. To investigate the fluid performance in tight clastic rock reservoir, some experiments and studies returned back to the essential issues, including the pore-throat structure and physical interaction of fluid-pore-wall in the tight reservoir [6,10,13,[15][16][17][18][19][20][21][22][23][24]. However, the pore-throat structures are various significantly in tight clastic rock reservoir and the fluid flow inside needs to be particularly concerned [25][26][27][28][29].…”

Section: Introductionmentioning

confidence: 99%

The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

et al. 2018

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The characteristics of porosity and permeability in tight clastic rock reservoir have significant difference from those in conventional reservoir. The increased exploitation of tight gas and oil requests further understanding of fluid performance in the nanoscale pore-throat network of the tight reservoir. Typical tight sandstone and siltstone samples from Ordos Basin were investigated, and rate-controlled mercury injection capillary pressure (RMICP) and nuclear magnetic resonance (NMR) were employed in this paper, combined with helium porosity and air permeability data, to analyze the impact of pore-throat structure on the storage and seepage capacity of these tight oil reservoirs, revealing the control factors of economic petroleum production. The researches indicate that, in the tight clastic rock reservoir, largest throat is the key control on the permeability and potentially dominates the movable water saturation in the reservoir. The storage capacity of the reservoir consists of effective throat and pore space. Although it has a relatively steady and significant proportion that resulted from the throats, its variation is still dominated by the effective pores. A combination parameter ( ) that was established to be as an integrated characteristic of pore-throat structure shows effectively prediction of physical capability for hydrocarbon resource of the tight clastic rock reservoir.

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Dynamic capillary effects in heterogeneous porous media

Cited by 63 publications

References 18 publications

Experimental investigation of hysteretic dynamic effect in capillary pressure–saturation relationship for two‐phase flow in porous media

Experimental investigation of hysteretic dynamic effect in capillary pressure–saturation relationship for two‐phase flow in porous media

Two-Phase Flow in Porous Media: Dynamic Capillarity and Heterogeneous Media

The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

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