Innovative methods for flow-unit and pore-structure analyses in a tight siltstone and shale gas reservoir

Clarkson, Christopher R.; Jensen, Jerry L.; Pedersen, Per Kent; Freeman, Melissa

doi:10.1306/05181110171

Cited by 182 publications

(80 citation statements)

References 19 publications

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“…The results of permeability measurements on seven Whitby Mudstone samples are summarised in Table 2 and are within the range previously reported for other mudstones (Morrow et al 1984;Katsube et al 1991;Coyner et al 1993;Schlömer & Krooss 1997;Dewhurst et al 1998;Kwon et al 2001;Hildenbrand et al 2004;Kwon et al 2004;Yang & Aplin 2007;Metwally & Sondergeld 2011;Chalmers et al 2012;Clarkson et al 2012a;Ghanizadeh et al 2014a;Ghanizadeh et al 2014b;Heller et al 2014;Morrow et al 2014). …”

Section: Discussion Permeabilitysupporting

confidence: 86%

“…Laboratory measurements of permeability of intact mudstone samples performed under reservoir conditions has yielded values between 10 -22 m 2 and 10 -12 m 2 (0.1 nD and 1 D) for flow both parallel and normal to layering (Morrow et al 1984;Katsube et al 1991;Coyner et al 1993;Schlömer & Krooss 1997;Dewhurst et al 1998;Faulkner & Rutter 2000;Kwon et al 2001;Hildenbrand et al 2004;Kwon et al 2004;Yang & Aplin 2007;Metwally & Sondergeld 2011;Chalmers et al 2012;Clarkson et al 2012a;Ghanizadeh et al 2014a;Ghanizadeh et al 2014b;Heller et al 2014;Morrow et al 2014). Where quantified, the relationship between permeability and effective pressure may be empirically described by either an exponential function (Katsube et al 1991;Schlömer & Krooss 1997;Chalmers et al 2012;Ghanizadeh et al 2014b) or a power law function (Katsube et al 1991;Kwon et al 2001;Metwally & Sondergeld 2011).…”

Section: Abstract: Mudstone Permeability Effective Pressure Shale Gasmentioning

confidence: 99%

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Microstructural controls on the pressure-dependent permeability of Whitby mudstone

Mckernan

Mecklenburgh²,

Rutter³

et al. 2017

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A combination of permeability and ultrasonic velocity measurements allied with image analysis is used to distinguish the primary microstructural controls on effective-pressure dependent permeability. Permeabilities of cylindrical samples of Whitby Mudstone were measured using the oscillating pore pressure method at confining pressures ranging between 30-95 MPa and pore pressures ranging between 1-80 MPa. The permeability-effective pressure relationship is empirically described using a modified effective pressure law in terms of confining pressure, pore pressure and a Klinkenberg effect. Measured permeability ranges between 3×10 -21 m 2 and 2 ×10 -19 m 2 (3 and 200 nd), and decreases by ~1 order of magnitude across the applied effective pressure range. Permeability is shown to be less sensitive to changes in pore pressure than changes in confining pressure, yielding permeability effective pressure coefficients ( ) between 0.42 and 0.97. Based on a pore-conductivity model which considers the measured changes in acoustic wave velocity and pore volume with pressure, the observed loss of permeability with increasing effective pressure is attributed dominantly to the progressive closure of bedding-parallel, crack-like pores associated with grain boundaries.Despite only constituting a fraction of the total porosity, these pores form an interconnected network that significantly enhances permeability at low effective pressures.The pre-publication reference is: Mckernan, R., Mecklenburgh, J., Rutter, E. H. and Taylor Progress in understanding fluid transport properties of mudstones is currently hindered by a scarcity of published experimental data. However, the ongoing expansion of the hydrocarbon industry into low-permeability unconventional resources is driving the demand for research and development in this field. Even when hydraulic fracture treatment is used to enhance production, flow of hydrocarbons into the fractures will be controlled ultimately by the microporous, low permeability matrix. Furthermore, during reservoir production pore-fluid pressure is progressively reduced, which acts to increase the in-situ Terzaghi effective pressure (defined as overburden pressure minus pore pressure), thereby decreasing permeability. The evolution of permeability of the matrix therefore determines the prediction of long-term production, which must take into account the effects of flow regime, multiphase flow, sorption effects, permeability anisotropy and, most importantly, the pressuredependence of permeability.Laboratory measurements of permeability of intact mudstone samples performed under reservoir conditions has yielded values between 10 -22 m 2 and 10 -12 m 2 (0.1 nD and 1 D) for flow both parallel and normal to layering (Morrow et al.

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Section: Discussion Permeabilitysupporting

confidence: 86%

Section: Abstract: Mudstone Permeability Effective Pressure Shale Gasmentioning

confidence: 99%

Microstructural controls on the pressure-dependent permeability of Whitby mudstone

Mckernan

Mecklenburgh²,

Rutter³

et al. 2017

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“…and estimates based on clay content and pore-size distribution [3][4].A method developed for profiling permeability along a shale core sample, which was calibrated using pulse permeability measurements. As gas is produced and reservoir pressure declines, two different processes alter the permeability of the rock.…”

Section: Introductionmentioning

confidence: 99%

Laboratory Investigation to Assess the Impact of Pore Pressure Decline and Confining Stress on Shale Gas Reservoirs

Memon¹,

Tunio²,

Mahesar³

et al. 2018

Mehran Univ. res. j. eng. technol.

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Four core samples of outcrop type shale from Mancos, Marcellus, Eagle Ford, and Barnett shale formations were studied to evaluate the productivity performance and reservoir connectivity at elevated temperature and pressure. These laboratory experiments were conducted using hydrostatic permeability system with helium as test gas primarily to avoid potential significant effects of adsorption and/or associated swelling that might affect permeability.It was found that the permeability reduction was observed due to increasing confining stress and permeability improvement was observed related to Knudsen flow and molecular slippage related to Klinkenberg effect. Through the effective permeability of rock is improved at lower pore pressures, as 1000 psi. The effective stress with relatively high flow path was identified, as 100-200 nm, in Eagle Ford core sample. However other three samples showed low marginal flow paths in low connectivity.

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“…Specifically, displacement experiments in the conventional cores are upgraded to those in the current microscopic real sandstone model that enables observation of oil and water movements under the microscope, which makes it possible to implement real-time observation and quantitative description analysis (Clarkson et al 2012;Guo et al 2007;Jia 2017;Xia et al 2013). However, there are relatively few studies on the microscopic displacement characteristics of oil and water in ultra-low permeability reservoirs, which needs to be further improved and supplemented.…”

Section: Introductionmentioning

confidence: 99%

Microscopic pore structure of Chang 63 reservoir in Huaqing oilfield, Ordos Basin, China and its effect on water flooding characteristics

Pan

Sun

Jin

et al. 2018

J Petrol Explor Prod Technol

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Chang 6 3 reservoir in Huaqing oilfield, Ordos Basin, China is featured by strong pore structure heterogeneity, which leads to prominent Jamin effect in the water flooding, difficult development process, low productivity, and massive residual oil. Accordingly, this study aims to explore the microscopic pore structure of Chang 6 3 reservoir and investigate its influence on the water flooding efficiency, based on a series of comprehensive analyses, including physical property analysis, casting thin section observation, scanning electron microscopy measurement, high-pressure mercury injection, constant rate mercury injection, and microscopic real sandstone water flooding model. It is demonstrated that gray and gray-brown feldspathic sandstone are the main reservoir lithology in the study area, with dominant pore types of residual intergranular pores and feldspar dissolution pores. Pore throat radius is unevenly distributed, and small and micro pores take the majority. Based on the comparison of capillary pressure curve characteristics and comprehensive analysis of corresponding parameters, the pore structure of the Chang 6 3 reservoir is divided into four types, namely types I-IV. They have different reservoir spaces, and their reservoir and seepage capacities decrease in the order of types I-IV pore structures. Moreover, displacement patterns in them are also different, with the finger-like-reticular displacement as the primary. In addition, pore throat radius and distribution play a critical role in the water flooding. It is also demonstrated that the water flooding efficiency increases with permeability and porosity, pore structure quality, and pore throat distribution evenness.

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Innovative methods for flow-unit and pore-structure analyses in a tight siltstone and shale gas reservoir

Cited by 182 publications

References 19 publications

Microstructural controls on the pressure-dependent permeability of Whitby mudstone

Microstructural controls on the pressure-dependent permeability of Whitby mudstone

Laboratory Investigation to Assess the Impact of Pore Pressure Decline and Confining Stress on Shale Gas Reservoirs

Microscopic pore structure of Chang 63 reservoir in Huaqing oilfield, Ordos Basin, China and its effect on water flooding characteristics

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