Modeling of Methane/Shale Excess Adsorption Under Reservoir Conditions
- Sheng Yang (University of Calgary) | Wei Wu (University of Calgary) | Jinze Xu (University of Calgary) | Dongqi Ji (University of Calgary) | Zhangxing Chen (University of Calgary) | Yizheng Wei (Computer Modeling Group)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- November 2018
- Document Type
- Journal Paper
- 1,027 - 1,034
- 2018.Society of Petroleum Engineers
- Volume Effects, Dubinin-Astakhov (DA) model, Methane Shale Adsorption, Reservoir Conditions
- 4 in the last 30 days
- 156 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 35.00|
Micropores and mesopores are the main storage volumes in shale matrix. Because of their small pore sizes, the force between pore boundary and gas molecules is significant. A larger amount of adsorbed gas is in a shale gas reservoir than in a conventional gas reservoir. People usually measure adsorption through volumetric methods under an isothermal condition. Because of a limitation of volumetric methods, only excess adsorption data are directly measured; then, a chosen model is applied to calculate an absolute adsorption through fitting the measured data.
An adsorption process induces changes in free-gas volume. However, the changes in absorbent volume and methane absorption into organic matter also alter the measured gas volume, which is widely neglected in previous studies. In this study, one volume term, which accounts for the unexpected changes in gas volumes caused by the other mechanisms except adsorption, is added to the Dubinin-Astakhov (DA) model (pore-filling theory). The in-situ methane is in a supercritical condition under reservoir conditions. Because of the lack of a saturation pressure of a supercritical fluid, an adsorbed-phase gas density is used to replace the saturation pressure in the DA model.
The modified model is validated by the isothermal adsorption data from four different shale plays. The calculated data by the proposed model have a better match with the measured data than those by the DA model. All shale samples demonstrate a nonmonotonic deformation of adsorbent (volume shrinkage in the low-pressure region, then swelling as pressure increases), which coincides with the results of previous molecular simulation. The key parameters of the proposed model such as a maximum adsorption capacity are more accurate and reasonable than the ones of the DA model. The proposed model provides a good approach to quantify absolute adsorption through experimental data, especially under reservoir conditions, and to emphasize the important effects of volume on methane/shale adsorption.
|File Size||557 KB||Number of Pages||8|
Beaton, A. P., Pawlowicz, J. G., Anderson, S. D. A. et al. 2010a. RockEval, Total Organic Carbon and Adsorption Isotherms of the Duvernay and Muskwa Formations in Alberta: Shale Gas Data Release. Energy Resources Conservation Board/Alberta Geological Survey Open File Report 2010-04.
Beaton, A. P., Pawlowicz, J. G., Anderson, S. D. A. et al. 2010b. RockEval, Total Organic Carbon and Adsorption Isotherms of the Montney Formations in Alberta: Shale Gas Data Release. Energy Resources Conservation Board/Alberta Geological Survey Open File Report 2010-04.
Busch, A. and Gensterblum, Y. 2011. CBM and CO2-ECBM Related Sorption Processes in Coal: A Review. International Journal of Coal Geology 87 (2): 49–71. https://doi.org/10.1016/j.coal.2011.04.011.
Charoensuppanimit, P., Mohammad, S. A., Robinson, R. L. et al. 2015. Modeling the Temperature Dependence of Supercritical Gas Adsorption on Activated Carbons, Coals and Shales. International Journal of Coal Geology 138: 113–126. https://doi.org/10.1016/j.coal.2014.12.008.
Cipolla, C. L., Lolon, E. P., Erdle, J. C. et al. 2010. Reservoir Modeling in Shale-Gas Reservoirs. SPE Res Eval & Eng 13 (4): 638–653. SPE-125530-PA. https://doi.org/10.2118/125530-PA.
Clarkson, C. R. and Haghshenas, B. 2013. Modeling of Supercritical Fluid Adsorption on Organic-Rich Shales and Coal. Presented at the SPE Unconventional Resources Conference-USA, The Woodlands, Texas, USA, 10–12 April. SPE-164532-MS. https://doi.org/10.2118/164532-MS.
Clarkson, C. R., Solano, N., Bustin, R. M. et al. 2013. Pore Structure Characterization of North American Shale Gas Reservoirs Using USANS/SANS, Gas Adsorption, and Mercury Intrusion. Fuel 103: 606–616. https://doi.org/10.1016/j.fuel.2012.06.119.
Do, D. D. 1998. Adsorption Analysis: Equilibria and Kinetics, Vol. 2. Imperial College Press.
Dubinin, M. M. and Cadenhead, D. A. 1975. Progress in Surface and Membrane Science, Vol. 9, pp. 1–316. New York: Academic Press.
Gasparik, M., Ghanizadeh, A., Bertier, P. et al. 2012. High-Pressure Methane Sorption Isotherms of Black Shales From the Netherlands. Energy & Fuels 26 (8): 4995–5004. https://doi.org/10.1021/ef300405g.
Gensterblum, Y., Van Hemert, P., Billemont, P. et al. 2010. European Inter-Laboratory Comparison of High-Pressure CO2 Sorption Isotherms II: Natural Coals. International Journal of Coal Geology 84 (2): 115–124. https://doi.org/10.1016/j.coal.2010.08.013.
George, J. S. and Barakat, M. A. 2001. The Change in Effective Stress Associated With Shrinkage From Gas Desorption in Coal. International Journal of Coal Geology 45 (2): 105–113. https://doi.org/10.1016/S0166-5162(00)00026-4.
Hartman, R. C., Ambrose, R. J., Akkutlu, I. Y. et al. 2011. Shale Gas-in-Place Calculations Part II—Multicomponent Gas Adsorption Effects. Presented at the North American Unconventional Gas Conference and Exhibition, The Woodlands, Texas, USA, 14–16 June. SPE-144097-MS. https://doi.org/10.2118/144097-MS.
Heller, R. and Zoback, M. 2014. Adsorption of Methane and Carbon Dioxide on Gas Shale and Pure Mineral Samples. Journal of Unconventional Oil and Gas Resources 8: 14–24. https://doi.org/10.1016/j.juogr.2014.06.001.
Kowalczyk, P., Furmaniak, S., Gauden, P. A. et al. 2010. Carbon Dioxide Adsorption-Induced Deformation of Microporous Carbons. The Journal of Physical Chemistry C 114 (11): 5126–5133. https://doi.org/10.1021/jp911996h.
Kowalczyk, P., Furmaniak, S., Gauden, P. A. et al. 2012. Methane-Induced Deformation of Porous Carbons: From Normal to High-Pressure Operating Conditions. The Journal of Physical Chemistry C 116 (2): 1740–1747. https://doi.org/10.1021/jp209364x.
Mosher, K., He, J., Liu, Y. et al. 2013. Molecular Simulation of Methane Adsorption in Micro- and Mesoporous Carbons With Applications to Coal and Gas Shale Systems. International Journal of Coal Geology 109–110: 36–44. https://doi.org/10.1016/j.coal.2013.01.001.
Ozdemir, E., Morsi, B. I., and Schroeder, K. 2003. Importance of Volume Effects to Adsorption Isotherms of Carbon Dioxide on Coals. Langmuir 19 (23): 9764–9773. https://doi.org/10.1021/la0258648.
Ozdemir, E., Morsi, B. I., and Schroeder, K. 2004. CO2 Adsorption Capacity of Argonne Premium Coals. Fuel 83 (7): 1085–1094. https://doi.org/10.1016/j.fuel.2003.11.005.
Reucroft, P. J. and Sethuraman, A. R. 1987. Effect of Pressure on Carbon Dioxide-Induced Coal Swelling. Energy & Fuels 1 (1): 72–75. https://doi.org/10.1021/ef00001a013.
Rexer, T. F., Benham, M. J., Aplin, A. C. et al. 2013. Methane Adsorption on Shale Under Simulated Geological Temperature and Pressure Conditions. Energy & Fuels 27 (6): 3099–3109. https://doi.org/10.1021/ef400381v.
Ross, D. J. and Bustin, R. M. 2009. The Importance of Shale Composition and Pore Structure Upon Gas Storage Potential of Shale Gas Reservoirs. Marine and Petroleum Geology 26 (6): 916–927. https://doi.org/10.1016/j.marpetgeo.2008.06.004.
Sakurovs, R., Day, S., Weir, S. et al. 2007. Application of a Modified Dubinin-Radushkevich Equation to Adsorption of Gases by Coals Under Supercritical Conditions. Energy & Fuels 21 (2): 992–997. https://doi.org/10.1021/ef0600614.
Sing, K. S. 1985. Reporting Physisorption Data for Gas/Solid Systems With Special Reference to the Determination of Surface Area and Porosity (Recommendations 1984). Pure and Applied Chemistry 57 (4): 603–619.
Sircar, S. 1999. Gibson Surface Excess for Gas Adsorption Revisited. Industrial & Engineering Chemistry Research 38 (10): 3670–3682. https://doi.org/10.1021/ie9900871.
Svrcek, W. Y. and Mehrotra, A. K. 1982. Gas Solubility, Viscosity and Density Measurements for Athabasca Bitumen. J Can Pet Technol 21 (4). PETSOC-82-04-02. https://doi.org/10.2118 https://doi.org/10.2118/82-04-02.
Yang, R. 1988. Gas Separation by Adsorption Processes. Series on Chemical Engineering: Vol. 1. Elsevier.
Yang, S., Chen, Z., Wei, Y. et al. 2015. A Simulation Model for Accurate Prediction of Uneven Proppant Distribution in the Marcellus Shale Coupled With Reservoir Geomechanics. Presented at the SPE Eastern Regional Meeting, Morgantown, West Virginia, USA, 13–15 October. SPE-177286-MS. https://doi.org/10.2118/177286-MS.
Yu, W. and Sepehrnoori, K. 2014. Simulation of Gas Desorption and Geomechanics Effects for Unconventional Gas Reservoirs. Fuel 116: 455–464. https://doi.org/10.1016/j.fuel.2013.08.032.