Abstract
Double porosity constitutive models are necessary components in mechanical analysis of fractured rocks. To solve the field constitutive equations, values of constitutive coefficients are required. Several theoretical expressions have been proposed to calculate the double porosity constitutive coefficients as their physical estimation is challenging due to a lack of efficiently designed experiments. Yet experimental determination of constitutive coefficients provides confidence in the accuracy of the models. Here, we present a methodological framework to determine new constitutive coefficients arising by coupling of gas sorption kinetics in the sorptive poromechanical model developed by the authors for double porosity media (Algazlan et al. 2022a). To physically characterise the new constitutive coefficients, we designed an innovative methodological process consisting of (i) obtaining gas diffusivities and Langmuir parameters by measuring gas uptake on different shales, (ii) computing the time evolutions of the free and adsorbed matrix gas concentrations, and (iii) optical imaging of temporal changes in the porosity of fractures. A novel shear-microscopy cell was used allowing stress application to the samples whilst being exposed to surficial fluid flow coupled with optical monitoring. The methodological framework resulted in the efficient determination of the new sorptive constitutive coefficients paving way for further advanced validation studies of multiphysics constitutive models.
Data availability
The datasets generated during and/or analysed during the current study are available from the corresponding author on reasonable request.
References
Aghighi, M.A., Lv, A., Siddiqui, M.A.Q., Masoumi, H., Thomas, R., Roshan, H.: A multiphysics field-scale investigation of gas pre-drainage in sorptive sediments. Int. J. Coal Geol. 261, 104098 (2022). https://doi.org/10.1016/j.coal.2022.104098
Aifantis, E.C.: On Barenblatt’s problem. Int. J. Eng. Sci. (1980). https://doi.org/10.1016/0020-7225(80)90033-6
Algazlan, M., Pinetown, K., Grigore, M., Chen, Z., Sarmadivaleh, M., Roshan, H.: Petrophysical assessment of Australian organic-rich shales: beetaloo, cooper and perth basins. J. Nat. Gas Sci. Eng. (2019). https://doi.org/10.1016/j.jngse.2019.102952
Algazlan, M., Abdul, M., Siddiqui, Q., Roshan, H.: A sorption-kinetics coupled dual-porosity poromechanical model for organic-rich shales. Comput. Geotech. 147, 104755 (2022). https://doi.org/10.1016/j.compgeo.2022.104755
Algazlan, M., Pinetown, K., Saghafi, A., Grigore, M., Roshan, H.: Role of organic matter and pore structure on CO2 adsorption of Australian organic-rich shales. Energy Fuels. 36, 5695–5708 (2022). https://doi.org/10.1021/acs.energyfuels.2c00657
Ashworth, M., Doster, F.: Foundations and their practical implications for the constitutive coefficients of poromechanical dual-continuum models. Transp. Porous Media. (2019). https://doi.org/10.1007/s11242-019-01335-6
Bai, M., Meng, F., Elsworth, D., Abousleiman, Y., Roegiers, J.C.: Numerical modelling of coupled flow and deformation in fractured rock specimens. Int. J. Numer. Anal. Methods Geomech. (1999). https://doi.org/10.1002/(SICI)1096-9853(199902)23:2%3c141::AID-NAG962%3e3.0.CO;2-G
Berre, I., Doster, F., Keilegavlen, E.: Flow in fractured porous media: a review of conceptual models and discretization approaches. Transp. Porous Media. (2019). https://doi.org/10.1007/s11242-018-1171-6
Berryman, J.G., Wang, H.F.: The elastic coefficients of double-porosity models for fluid transport in jointed rock. J. Geophys. Res. (1995). https://doi.org/10.1029/95jb02161
Biot, M.A.: Thermoelasticity and irreversible thermodynamics. J. Appl. Phys. 58, 452369 (1956a). https://doi.org/10.1063/1.1722351
Biot, M.A.: Theory of propagation of elastic waves in a fluid-saturated porous solid II. higher frequency range. J. Acoust. Soc. Am. (1956b). https://doi.org/10.1121/1.1908241
Biot, M.A.: Nonlinear and semilinear rheology of porous solids. J. Geophys. Res. (1973). https://doi.org/10.1029/jb078i023p04924
Blaber, J., Adair, B., Antoniou, A.: Ncorr: Open-source 2D digital image correlation matlab software. Exp. Mech. 55, 1105–1122 (2015). https://doi.org/10.1007/s11340-015-0009-1
Coussy, O.: Poromechanics. (2005). https://doi.org/10.1002/0470092718
Crank, J.: The mathematics of diffusion. 2nd Edn. (1979) DOI: https://doi.org/10.1088/0031-9112/26/11/044
Detournay, E., Cheng, A.H.D.: Fundamentals of poroelasticity. Compr. Rock Eng. 2(12), 901152432 (1993). https://doi.org/10.1017/cbo9781139051132.003
Elsworth, D., Bai, M.: Flow-deformation response of dual-porosity media. J. Geotech. Eng. (1992). https://doi.org/10.1061/(ASCE)0733-9410(1992)118:1(107)
Espinoza, D.N., Vandamme, M., Pereira, J.M., Dangla, P., Vidal-Gilbert, S.: Measurement and modeling of adsorptive-poromechanical properties of bituminous coal cores exposed to CO2: adsorption, swelling strains, swelling stresses and impact on fracture permeability. Int. J. Coal Geol. (2014). https://doi.org/10.1016/j.coal.2014.09.010
Espinoza, D.N., Vandamme, M., Dangla, P., Pereira, J.M., Vidal-Gilbert, S.: Adsorptive-mechanical properties of reconstituted granular coal: experimental characterization and poromechanical modeling. Int. J. Coal Geol. (2016). https://doi.org/10.1016/j.coal.2016.06.003
Gale, J.F.W., Laubach, S.E., Olson, J.E., Eichhubl, P., Fall, A.: Natural fractures in shale: a review and new observations. Am. Assoc. Pet. Geol. Bull. (2017). https://doi.org/10.1306/08121413151
Gutierrez-Sosa, L., Geiger, S., Doster, F.: Poro-mechanical coupling for flow diagnostics. Transp. Porous Media. 145, 389–411 (2022). https://doi.org/10.1007/s11242-022-01857-6
Haghshenas, B., Aquino, S.D., Clarkson, C.R., Chen, S.: Use of gas adsorption data to extract diffusivity/permeability from shale reservoir drill cuttings: Implications for reservoir characterization of horizontal laterals in Western Canadian shale plays. In: Society of Petroleum Engineers—SPE/CSUR Unconventional Resources Conference (2015)
Khalili, N., Selvadurai, A.P.S.: A fully coupled constitutive model for thermo-hydro-mechanical analysis in elastic media with double porosity. Geophys. Res. Lett. (2003). https://doi.org/10.1029/2003GL018838
Lei, X., Wong, H., Fabbri, A., Limam, A., Cheng, Y.M.: A chemo-elastic-plastic model for unsaturated expansive clays. Int. J. Solids Struct. (2016). https://doi.org/10.1016/j.ijsolstr.2016.01.008
Lewis, R.W., Ghafouri, H.R.: A novel finite element double porosity model for multiphase flow through deformable fractured porous media. Int. J. Numer. Anal. Methods Geomech. (1997). https://doi.org/10.1002/(SICI)1096-9853(199711)21:11%3c789::AID-NAG901%3e3.0.CO;2-C
Li, Z.Z., Min, T., Kang, Q., He, Y.L., Tao, W.Q.: Investigation of methane adsorption and its effect on gas transport in shale matrix through microscale and mesoscale simulations. Int. J. Heat Mass Transf. (2016). https://doi.org/10.1016/j.ijheatmasstransfer.2016.03.039
Liu, C., Abousleiman, Y.N.: Shale dual-porosity dual-permeability poromechanical and chemical properties extracted from experimental pressure transmission tests. J. Eng. Mech. (2017). https://doi.org/10.1061/(asce)em.1943-7889.0001333
Lv, A., Masoumi, H., Walsh, S.D.C., Roshan, H.: Elastic-softening-plasticity around a borehole: an analytical and experimental study. Rock Mech. Rock Eng. (2018). https://doi.org/10.1007/s00603-018-1650-7
Lv, A., Ramandi, H.L., Masoumi, H., Saadatfar, M., Regenauer-Lieb, K., Roshan, H.: Analytical and experimental investigation of pore pressure induced strain softening around boreholes. Int. J. Rock Mech. Min. Sci. (2019). https://doi.org/10.1016/j.ijrmms.2018.11.001
Lv, A., Ali Aghighi, M., Masoumi, H., Roshan, H.: On swelling stress–strain of coal and their interaction with external stress. Fuel 485, 122543 (2022). https://doi.org/10.1016/j.fuel.2021.122534
Lv, A., Bahaaddini, M., Masoumi, H., Roshan, H.: The combined effect of fractures and mineral content on coal hydromechanical response. Bull. Eng. Geol. Environ. 81, 2669 (2022). https://doi.org/10.1007/s10064-022-02669-0
Rani, S., Prusty, B.K., Pal, S.K.: Adsorption kinetics and diffusion modeling of CH4 and CO2 in Indian shales. Fuel (2018). https://doi.org/10.1016/j.fuel.2017.11.124
Roshan, H., Fahad, M.: Chemo-poroplastic analysis of a borehole drilled in a naturally fractured chemically active formation. Int. J. Rock Mech. Min. Sci. (2012). https://doi.org/10.1016/j.ijrmms.2012.03.004
Shi, R., Liu, J., Wang, X., Elsworth, D., Wang, Z., Wei, M., Cui, G.: Experimental observations of gas-sorption-induced strain gradients and their implications on permeability evolution of shale. Rock Mech. Rock Eng. (2021). https://doi.org/10.1007/s00603-021-02473-4
Siddiqui, M.A.Q., Chen, X., Iglauer, S., Roshan, H.: A multiscale study on shale wettability: Spontaneous imbibition vs contact angle. Water Resour. Res. 753, 3 (2019). https://doi.org/10.1029/2019WR024893
Siddiqui, M.A.Q., Lv, A., Regenauer-Lieb, K., Roshan, H.: A novel experimental system for measurement of coupled multi-physics-induced surface alteration processes in geomaterials. Meas. J. Int. Meas. Confed. (2020). https://doi.org/10.1016/j.measurement.2020.108211
Siddiqui, M.A.Q., Serati, M., Regenauer-lieb, K., Roshan, H.: A thermodynamics-based multi-physics constitutive model for variably saturated fractured sorptive rocks. Int. J. Rock Mech. Min. Sci. 158, 105202 (2022). https://doi.org/10.1016/j.ijrmms.2022.105202
Smith, D.M., Williams, F.L.: Diffusion models for gas production from coal. Fuel (1984). https://doi.org/10.1016/0016-2361(84)90047-4
Svanadze, M.: Fundamental solution in the theory of consolidation with double porosity. J. Mech. Behav. Mater. (2011). https://doi.org/10.1515/jmbm.2005.16.1-2.123
Terzaghi, K.: Theor. Soil Mech. (1943). https://doi.org/10.1002/9780470172766
Tinni, A., Fathi, E., Agarwal, R., Sondergeld, C., Akkutlu, Y., Rai, C.: Shale permeability measurements on plugs and crushed samples. In: Society of Petroleum Engineers - SPE Canadian Unconventional Resources Conference 2012, CURC 2012 (2012) DOI: https://doi.org/10.2118/162235-ms
Wilson, R.K., Aifantis, E.C.: On the theory of consolidation with double porosity. Int. J. Eng. Sci. (1982). https://doi.org/10.1016/0020-7225(82)90036-2
Funding
The authors acknowledge the support of the Australian Research Council (ARC) through the Discovery Project Grant (DP200102517). Muath Algazlan would like to further acknowledge the graduate fellowship provided by Saudi Aramco.
Author information
Authors and Affiliations
Contributions
All authors contributed to the study conception and design. Material preparation, data collection and analysis were performed by M.A., and M.A.Q.S. The first draft of the manuscript was written by M.A., and all authors commented on previous versions of the manuscript. All authors read and approved the final manuscript.
Corresponding author
Ethics declarations
Competing interests
The authors have no relevant financial or non-financial interests to disclose.
Additional information
Publisher's Note
Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations.
Appendices
Appendix A
Samples Description and Experimental Procedures
Shale samples from three different local Australian basins were used for the gas uptake and diffusivity measurements and the microscopy-based investigations. Using a RockLab benchtop ring mill, samples from the three different basins were ground down to an average particle size of ~ 200 µm, to be used for the gas uptake measurements. The powdered samples were then left overnight in a vacuum oven to remove moisture. Another set of samples from the MVBF was cut into cuboids using an electrical circular saw cutting machine. Samples were secured and hold in place firmly during cutting to minimise/eliminate damage. Air was used instead of water to clean/cool the blade whilst cutting the samples. The surfaces of the cut samples were then polished using a sandpaper with 1000 p grit-size maintaining a constant polishing time for consistency across all samples.
The gas uptake measurements were conducted using a system developed by CSIRO Energy North Ryde laboratories. This system was designed based on a volumetric method, whereby the mass of adsorbed gas is calculated from direct measurements of gas pressures in various parts of the system. It allows simultaneous measurements of four samples. The samples are generally crushed to less than 200 µm particle size. The system requires feeding samples of ~100 g mass and can operate at temperatures of up to 70 °C and pressures of up to 15 MPa. To increase the gas pressure, the adsorbent gas is first fed from a set of cylinders into a dual ISCO pumps system. Once the gas pressure reached a pre-set level, it is injected into a reference cell. This reference cell is connected to 4 sample cells via shut-off valves. All cells are mounted in a temperature-controlled water bath. A thermocline unistat heater circulator is used to heat the water bath to the desired temperature and a thermocouple connected to a computer records the temperature values in real-time. During measurements, gas pressure values in reference and sample cells are recorded continuously through pressure transducers connected to a computer. The pressure sensors have a 0–15 MPa range and accuracy of ±0.04%. The valves into and between the reference cell and the four sample cells are controlled pneumatically. A vacuum pump is connected to the system and used to keep the cells under vacuum at the start of the experiment. The volume of the reference cell and the empty sample cells is accurately measured and used in data processing.
The prepared cuboid shale samples were hosted in the high-pressure shear cell, which allows for stress application to the samples whilst exposing them to fluid flow and monitoring their surface changes through a scratch resistant sapphire glass window that is fitted and screwed on top of the housed sample with a flat O-ring. Two Teledyne ISCO pumps filled with hydraulic oil were connected to the cell’s two hydraulic rams that push steel platens against the housed shale sample creating the desired stresses, provided that the sides opposite to the rams are fixed. Another ISCO pump filled with injection gas (i.e. either helium or CO2) is connected to the upstream port and is used to circulate the gas and control its pressure, with the downstream port being fitted with a Swagelok high-pressure valve. The gas enters from the upstream port and is introduced first to the top face of the sample. Applied gas pressures and confining stresses were monitored using high-precision digital pressure transducers connected to a computer for data acquisition and recording. The changes in fractures’ apertures were captured using ISCapture, an image acquisition software, at a magnification value of 90x with an image pixel resolution of 0.5 μm and a capture rate of one frame/second.
Appendix B
Numerical Simulations
Two physics interfaces were used to model the gas diffusion and adsorption, a built-in transport of diluted species in porous media interface for CO2 diffusion utilising the equation:
where \({c}_{i}\) is the free gas concentrations, and \(J_{i} = - D_{i} .\nabla c_{i}\) with \({D}_{i}\) being the diffusion coefficient. A general form PDE interface was utilised for modelling CO2 adsorption using the following equation:
where \({c}_{s}\) is the adsorbed gas concentrations, and R is the source/sink term and is defined as follows:
where \({k}_{ads}\) is the adsorption rate, \({k}_{des}\) is the desorption rate, and \({c}_{max}\) is the maximum surface sorption concentrations. The initial/boundary gas concentrations were calculated from the CO2 injection pressure value of 30 bar, used in the fracture investigation, and the void space between the shear cell’s closed chamber and the hosted sample at the experiment’s temperature, i.e. 25 °C. The values used in the model for CO2 diffusivity coefficient and CO2 Langmuir parameters were the same values obtained from the CO2 gas uptake measurements introduced earlier, at the same temperature and pressure conditions. Finally, a source/sink term was used to couple gas diffusion with gas sorption.
Rights and permissions
About this article
Cite this article
Algazlan, M., Siddiqui, M.A.Q., Regenauer-Lieb, K. et al. A Methodological Determination of Sorptive Poromechanical Constitutive Coefficients for Double Porosity Shales. Transp Porous Med 150, 753–768 (2023). https://doi.org/10.1007/s11242-023-01995-5
Received:
Accepted:
Published:
Issue Date:
DOI: https://doi.org/10.1007/s11242-023-01995-5