Tight gas sands permeability estimation from mercury injection capillary pressure and nuclear magnetic resonance data

Rezaee, Reza; Saeedi, Ali; Clennell, Ben

doi:10.1016/j.petrol.2011.12.014

Cited by 316 publications

(166 citation statements)

References 7 publications

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“…Since it is generally accepted that shale porosities are highly stress dependent (Bustin et al, 2008;Rezaee et al, 2012;Clarkson et al, 2011), a total of 9 core plugs were selected to conduct helium porosimetry under confining pressures simulating overburden conditions. To perform this experiment, samples were placed into individual thick-walled rubber sleeves and then assembled into a hydrostatic cell.…”

Section: Helium Porosimetrymentioning

confidence: 99%

Experimental investigation of the pore structure characteristics of the Garau gas shale formation in the Lurestan Basin, Iran

Vafaie

Habibnia

Moallemi³

2015

Journal of Natural Gas Science and Engineering

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Section: Helium Porosimetrymentioning

confidence: 99%

Experimental investigation of the pore structure characteristics of the Garau gas shale formation in the Lurestan Basin, Iran

Vafaie

Habibnia

Moallemi³

2015

Journal of Natural Gas Science and Engineering

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“…Pittman [16] extended Winland's work and pointed out that the pore size at 25% mercury saturation controls the permeability. For tight gas sands, Rezaee et al [17] indicated that the pore size at 10% mercury saturation is a good permeability predictor. For shale media, very high pressure would be required for mercury to enter small pores around 3.6 nm [18].…”

Section: Introductionmentioning

confidence: 99%

A Theoretical Analysis of Pore Size Distribution Effects on Shale Apparent Permeability

Tian

Ren

et al. 2017

Geofluids

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Apparent permeability is an important input parameter in the simulation of shale gas production. Most apparent permeability models assume a single pore size. In this study, we develop a theoretical model for quantifying the effect of pore size distribution on shale apparent permeability. The model accounts for the nonuniform distribution of pore sizes, the rarefaction effect, and gas characteristics. The model is validated against available experimental data. Theoretical calculations show that the larger the pore radius, the larger the apparent permeability. Moreover, the apparent permeability increases with an increase in the width of pore size distribution, with this effect being much more pronounced at low pressure than at high pressure.

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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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Tight gas sands permeability estimation from mercury injection capillary pressure and nuclear magnetic resonance data

Cited by 316 publications

References 7 publications

Experimental investigation of the pore structure characteristics of the Garau gas shale formation in the Lurestan Basin, Iran

Experimental investigation of the pore structure characteristics of the Garau gas shale formation in the Lurestan Basin, Iran

A Theoretical Analysis of Pore Size Distribution Effects on Shale Apparent Permeability

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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