The importance of shale composition and pore structure upon gas storage potential of shale gas reservoirs

Ross, Daniel; Bustin, R. Marc

doi:10.1016/j.marpetgeo.2008.06.004

Cited by 1,833 publications

(1,403 citation statements)

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“…Unexpectedly, the evaluation of the CH 4 adsorption capacity on montmorillonite and kaolinite showed higher CH 4 uptake by kaolinite than Na + -saturated montmorillonite at low pressures (≤0.3 MPa) (Cheng and Huang, 2004). Ross and Bustin further found that at low pressures (6.0 MPa), the CH 4 adsorption capacities of illite (0.4 cm 3 /g) and montmorillonite (0.6 cm 3 /g) were lower than that of kaolinite (0.7 cm 3 /g) on a moisture-equilibrated basis, but were significantly higher (montmorillonite: 2.9 cm 3 /g and illite: 2.1 cm 3 /g) than that of kaolinite (0.7 cm 3 /g) under dry conditions (Ross and Bustin, 2009).…”

Section: Introductionmentioning

confidence: 87%

“…Pressures and temperatures were proposed to be the main factors that influence CH 4 adsorption and CH 4 reservoir (Cheng and Huang, 2004;Cui et al, 2009;Lu et al, 1995;Ross and Bustin, 2009). The experimental evaluation showed that the CH 4 adsorption capacity of shale increases with the increment of pressure (Cheng and Huang, 2004;Loucks et al, 2009;Lu et al, 1995;Bustin, 2007, 2008), implying that the high pressures in the actual shale gas reservoir might result in a large CH 4 adsorption amount.…”

Section: Introductionmentioning

confidence: 99%

“…However, Schettler and Parmoly proposed that clay minerals played an important role in CH 4 adsorption in their study of CH 4 adsorption on shale samples from Appalachian basin shales, which had low kerogen contents (Schettler and Parmoly, 1990). Since then, CH 4 adsorption on clay minerals has been investigated by others (Cheng and Huang, 2004;Lu et al, 1995;Ross and Bustin, 2009). In experimental measurements of CH 4 adsorption on clay minerals at various temperatures and low pressures, clay minerals were found to provide adsorption sites and space for CH 4 storage (Cheng and Huang, 2004;Lu et al, 1995;Ross and Bustin, 2009).…”

Section: Introductionmentioning

confidence: 99%

“…Since then, CH 4 adsorption on clay minerals has been investigated by others (Cheng and Huang, 2004;Lu et al, 1995;Ross and Bustin, 2009). In experimental measurements of CH 4 adsorption on clay minerals at various temperatures and low pressures, clay minerals were found to provide adsorption sites and space for CH 4 storage (Cheng and Huang, 2004;Lu et al, 1995;Ross and Bustin, 2009). The maximum CH 4 adsorption capacity of pure illite at 37.8°C and ≤8.0 MPa was higher than that of shale samples obtained from wells of Michigan, West Virginia and Kentucky, USA (Lu et al, 1995).…”

Section: Introductionmentioning

confidence: 99%

“…One of the major reasons for this lack of progress is the coexistence of organic matters during adsorption measurements; thus, the effects of organic matter could not be avoided (Ross and Bustin, 2009), which prevented the adsorption mechanism of clay minerals from being exclusively addressed. Another major reason is that the pressure, which is an important evaluation parameter of the CH 4 adsorption capacity, ranged less extensively (≤8.0 MPa) in the previous studies (Cheng and Huang, 2004;Crosdale et al, 1998;Lu et al, 1995;Ross and Bustin, 2007;Sun et al, 2009).…”

Section: Introductionmentioning

confidence: 99%

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High-pressure adsorption of methane on montmorillonite, kaolinite and illite

Liu

Yuan

Liu

et al. 2013

Applied Clay Science

162

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Section: Introductionmentioning

confidence: 87%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

High-pressure adsorption of methane on montmorillonite, kaolinite and illite

Liu

Yuan

Liu

et al. 2013

Applied Clay Science

162

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Water Saturation Relations and Their Diffusion‐Limited Equilibration in Gas Shale: Implications for Gas Flow in Unconventional Reservoirs

Tokunaga

Shen

Wan

et al. 2017

Water Resources Research

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Large volumes of water are used for hydraulic fracturing of low permeability shale reservoirs to stimulate gas production, with most of the water remaining unrecovered and distributed in a poorly understood manner within stimulated regions. Because water partitioning into shale pores controls gas release, we measured the water saturation dependence on relative humidity (rh) and capillary pressure (Pc) for imbibition (adsorption) as well as drainage (desorption) on samples of Woodford Shale. Experiments and modeling of water vapor adsorption into shale laminae at rh = 0.31 demonstrated that long times are needed to characterize equilibrium in larger (5 mm thick) pieces of shales, and yielded effective diffusion coefficients from 9 × 10−9 to 3 × 10−8 m2 s−1, similar in magnitude to the literature values for typical low porosity and low permeability rocks. Most of the experiments, conducted at 50°C on crushed shale grains in order to facilitate rapid equilibration, showed significant saturation hysteresis, and that very large Pc (∼1 MPa) are required to drain the shales. These results quantify the severity of the water blocking problem, and suggest that gas production from unconventional reservoirs is largely associated with stimulated regions that have had little or no exposure to injected water. Gravity drainage of water from fractures residing above horizontal wells reconciles gas production in the presence of largely unrecovered injected water, and is discussed in the broader context of unsaturated flow in fractures.

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Interactions Between Stratigraphy and Interfacial Properties on Flow and Trapping in Geologic Carbon Storage

Liang

Clarens

2018

Water Resources Research

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Gas leakage from geologic carbon storage sites could undermine the long‐term goal of reducing emissions to the atmosphere and negatively impact groundwater resources. Despite this, there remain uncertainties associated with the transport processes that would govern this leakage. These stem from the complex interaction between governing forces (e.g., gravitational, viscous, and capillary), the heterogeneous nature of the porous media, and the characteristic length scales of these leakage events, all of which impact the CO2 fluid flow processes. Here we assessed how sub‐basin‐scale horizons in porous media could impact the migration and trapping of a CO2 plume. A high‐pressure column packed with two layers of sand with different properties (e.g., grain size and wettability) was used to create a low‐contrast stratigraphic horizon. CO2 in supercritical or liquid phase was injected into the bottom of the column under various conditions (e.g., temperature, pressure, and capillary number) and the transport of the resulting plume was recorded using electrical resistivity. The results show that CO2 trapping was most strongly impacted by shifting the wettability balance to mixed‐wet conditions, particularly for residual saturation. A 16% increase in the cosine of the contact angle for a mixed‐wet sand resulted in nearly twice as much residual trapping. Permeability contrast, pressure, and temperature also impacted the residual saturation but to a lesser extent. Flow rate affected the dynamics of saturation profile development, but the effect is transient, suggesting that the other effects observed here could apply to a broad range of leakage conditions.

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The importance of shale composition and pore structure upon gas storage potential of shale gas reservoirs

Cited by 1,833 publications

References 65 publications

High-pressure adsorption of methane on montmorillonite, kaolinite and illite

High-pressure adsorption of methane on montmorillonite, kaolinite and illite

Water Saturation Relations and Their Diffusion‐Limited Equilibration in Gas Shale: Implications for Gas Flow in Unconventional Reservoirs

Interactions Between Stratigraphy and Interfacial Properties on Flow and Trapping in Geologic Carbon Storage

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