A unified apparent porosity/permeability model of organic porous media: Coupling complex pore structure and multi-migration mechanism
Abstract view|909|times PDF download|248|times
Abstract
Shale gas resources are widely distributed and abundant in China, which is an important field for strategic replacement and development of oil and gas resources. Shale gas reservoirs has adsorption gas, free gas. The structure of different scale media, such as organic pores, are difficult to describe. Therefore, flow behavior cannot be simulated by conventional method. In this paper, the micro-scale fluid migration in shale gas reservoirs was established in a single pore, which coupled surface diffusion, slip flow, and viscous flow. On this basis, the fractal scale relationship was applied to describe the distribution of pore radius, tortuosity, and surface roughness. Based on the comprehensive characterization of static structure haracteristics of porous media, such as pore size distribution, pore shapes, tortuosity and surface roughness, and the dynamic pore size influenced by various stresses, the apparent porosity/permeability model of organic matter considering single-phase multi-migration mechanism was established. The gas migration in organic porous media was analyzed with the apparent porosity/permeability model. The results show that the small pores in organic matter are the main storage space of gas (more than 95% of the gas is stored in pores less than 10 nm), and the large pores are gas flow channel. At the same time, the apparent porosity/permeability model combined with conventional Darcy equation can be used to describe the single-phase gas flow in shale gas reservoirs.
Cited as: Sheng, G., Su, Y., Zhao, H., Liu, J. A unified apparent porosity/permeability model of organic porous media: Coupling complex pore structure and multi-migration mechanism. Advances in Geo-Energy Research, 2020, 4(2): 115-125, doi: 10.26804/ager.2020.02.01
Keywords
Full Text:
PDFReferences
Afsharpoor, A., Javadpour, F. Liquid slip flow in a network of shale noncircular nanopores. Fuel 2016, 180: 580-590.
An, C., Fang, Y., Liu, S., et al. Impacts of matrix shrinkage and stress changes on permeability and gas production of organic-rich shale reservoirs. Paper SPE 186029 Presented at Reservoir Characterisation and Simulation Conference and Exhibition, Abu Dhabi, UAE, 8-10 May, 2017.
Brown, G.P., DiNardo, A., Cheng G.K., et al. The flow of gases in pipes at low pressures. J. Appl. Phys. 1946, 17(10): 802-813.
Cai, J., Lin, D., Singh, H., et al. Shale gas transport model in 3D fractal porous media with variable pore sizes. Mar. Pet. Geol. 2018, 98: 437-447.
Chai, D., Yang, G., Fan, Z., et al. Gas transport in shale matrix coupling multilayer adsorption and pore confinement effect. Chem. Eng. J. 2019, 370: 1534-1549.
Chen, S., Zhu, Y., Wang, H., et al. Shale gas reservoir characterisation: A typical case in the southern Sichuan Basin of China. Energy 2011, 36(11): 6609-6616.
Civan, F. Effective correlation of apparent gas permeability in tight porous media. Transp. Porous Media 2010, 82(2): 375-384.
Coppens, M.O., Dammers, A.J. Effects of heterogeneity on diffusion in nanopores-from inorganic materials to protein crystals and ion channels. Fluid Phase Equilibr. 2006, 241(1-2): 308-316.
Curtis, M.E., Cardott, B.J., Sondergeld, C.H., et al. Development of organic porosity in the Woodford Shale with increasing thermal maturity. Int. J. Coal Geol. 2012, 103: 26-31.
Dong, J., Hsu, J., Wu, W., et al. Stress dependence of the permeability and porosity of sandstone and shale from TCDP Hole-A. Int. J. Rock Mech. Min. Sci. 2010, 47(7): 1141-1157.
Du, F., Nojabaei, B. A review of gas injection in shale reservoirs: Enhanced oil/gas recovery approaches and greenhouse gas control. Energies 2019, 12(12): 2355.
Freeman, C.M., Moridis, G.J., Blasingame, T.A. A numerical study of microscale flow behavior in tight gas and shale gas reservoir systems. Transp. Porous Media 2011, 90(1): 253-268.
Javadpour, F. Nanopores and apparent permeability of gas flow in mudrocks (shales and siltstone). J. Can. Pet. Technol. 2009, 48(8): 16-21.
Javadpour, F., Fisher, D., Unsworth, M. Nanoscale gas flow in shale gas sediments. J. Can. Pet. Technol. 2007, 46(10): 55-61.
Karniadakis, G., Beskok, A., Aluru, N. Microflows and Nanoflows: Fundamentals and Simulation. New York, USA, Springer Science & Business Media, 2005.
Krishna, R., Wesselingh, J.A. The Maxwell-Stefan approach to mass transfer. Chem. Eng. Sci. 1997, 52(6): 861-911.
Li, C., Lin, M., Ji, L., et al. Investigation of intermingled fractal model for organic-rich shale. Energy Fuels 2017, 31(9): 8896-8909.
Li, J., Chen, Z., Wu, K., et al. Effect of water saturation on gas slippage in circular and angular pores. AIChE J. 2018, 64(9): 3529-3541.
Li, X., Zhang, L. Characterization of dual-structure pore-size distribution of soil. Can. Geotech. J. 2009, 46(2): 129-141.
Liu, Y., Zhu, Y. Comparison of pore characteristics in the coal and shale reservoirs of Taiyuan Formation, Qinshui Basin, China. Int. J. Coal Sci. Technol. 2016, 3(3): 330-338.
Loucks, R.G., Reed, R.M., Ruppel, S.C., et al. Morphology, genesis, and distribution of nanometer-scale pores in siliceous mudstones of the Mississippian Barnett Shale. J. Sediment. Res. 2009, 79(12): 848-861.
Lu, X., Li, F., Watson, A.T. Adsorption measurements in Devonian shales. Fuel 1995, 74(4): 599-603.
Majumdar, A., Bhushan, B. Role of fractal geometry in roughness characterization and contact mechanics of surfaces. J. Tribol. 1990, 112: 205-216.
Mehmani, A., Prodanovi, M., Javadpour, F. Multiscale, multiphysics network modeling of shale matrix gas flows. Transp. Porous Media 2013, 99(2): 377-390.
Meng, M., Baldino, S., Miska, S.Z., et al. Wellbore stability in naturally fractured formations featuring dual-porosity/single-permeability and finite radial fluid discharge. J. Pet. Sci. Eng. 2019, 174: 790-803.
Mokhtari, M., Alqahtani, A.A., Tutuncu, A.N., et al. Stress-dependent permeability anisotropy and wettability of shale resources. Abstracts URTeC 1555068 Presnted at Unconventional Resources Technology Conference, Denver, Colorado, 12-14 August, 2013.
Mortensen, N.A., Okkels, F., Bruus, H. Reexamination of Hagen-Poiseuille flow: Shape dependence of the hydraulic resistance in microchannels. Phys. Rev. E 2005, 71(5): 057301.
Ren, W., Li, G., Tian, S., et al. An analytical model for real gas flow in shale nanopores with non-circular cross-section. AIChE J. 2016, 62(8): 2893-2901.
Roy, S., Raju, R., Chuang, H.F., et al. Modeling gas flow through microchannels and nanopores. J. Appl. Phys. 2003, 93(8): 4870-4879.
Saurabh, S., Harpalani, S. Stress path with depletion in coalbed methane reservoirs and stress-based permeability modeling. Int. J. Coal Geol. 2018, 185: 12-22.
Sheng, G. Research on characterization of multi-scale media and flow simulation of shale gas reservoirs. Qingdao, China University of Petroleum (East China), 2019. (in Chinese)
Sheng, G., Javadpour, F., Su, Y. Effect of microscale media compressibility on apparent porosity and permeability in shale gas reservoirs. Int. J. Heat Mass Transf. 2018, 120: 56-65.
Sheng, G., Javadpour, F., Su, Y. Dynamic porosity and apparent permeability in porous organic matter of shale gas reservoirs. Fuel 2019, 251: 341-351.
Sheng, G., Zhao, H., Su, Y., et al. An analytical model to couple gas storage and transport capacity in organic matter with noncircular pores. Fuel 2020, 268: 117288.
Shi, J., Durucan, S. Drawdown induced changes in permeability of coalbeds: A new interpretation of the reservoir response to primary recovery. Transp. Porous Media 2004, 56(1): 1-16.
Singh, H., Javadpour, F. Nonempirical apparent permeability of shale. Paper URTeC 1578037 Presented at the Unconventional Resources Conference, Denver, Colorado, USA, 12-14 August, 2013.
Singh, H., Javadpour, F., Tavakkol, A.E., et al. Nonempirical apparent permeability of shale. SPE Reserv. Eval. Eng. 2014, 17(3): 414-424.
Sone, Y. Kinetic Theory and Fluid Dynamics. New York, USA, Springer Science & Business Media, 2012.
Song, W., Wang, D., Yao, J., et al. Multiscale image-based fractal characteristic of shale pore structure with implication to accurate prediction of gas permeability. Fuel 2019, 241: 522-532.
Wang, D., Yao, J., Chen, Z., et al. Gas-water two-phase transport properties in shale microfractures. Chinese Science Bulletin 2019, 64(31): 3232-3243. (in Chinese)
Wang, F., Jiao, L., Lian, P., et al. Apparent gas permeability, intrinsic permeability and liquid permeability of fractal porous media: Carbonate rock study with experiments and mathematical modelling. J. Pet. Sci. Eng. 2019, 173: 1304-1315.
Wang, F., Reed, R.M. Pore networks and fluid flow in gas shales. Paper SPE 124253 Presented at Annual Technical Conference and Exhibition, New Orleans, Louisiana, 4-7 October, 2009.
Wang, G., Ju, Y. Organic shale micropore and mesopore structure characterization by ultra-low pressure N2 physisorption: Experimental procedure and interpretation model. J. Nat. Gas Sci. Eng. 2015, 27: 452-465.
Wang, X., Sheng, J. Multi-scaled pore network modeling of gas-water flow in shale formations. J. Pet. Sci. Eng. 2019, 177: 899-908.
Wheatcraft, S.W., Tyler, S.W. An explanation of scale-dependent dispersivity in heterogeneous aquifers using concepts of fractal geometry. Water Resour. Res. 1988, 24(4): 566-578.
Wu, K., Chen, Z., Li, X. Real gas transport through nanopores of varying cross-section type and shape in shale gas reservoirs. Chem. Eng. J. 2015, 281: 813-825.
Wu, K., Li, X., Guo, C., et al. A unified model for gas transfer in nanopores of shale-gas reservoirs: Coupling pore diffusion and surface diffusion. SPE J. 2016, 21(5): 1583-1611.
Xu, J., Wu, K., Yang, S., et al. Real gas transport in tapered noncircular nanopores of shale rocks. AIChE J. 2017, 63(7): 3224-3242.
Xu, S., Tang, X., Torres-Verdn, C., et al. Seismic shear wave anisotropy in cracked rocks and an application to hydraulic fracturing. Geophys. Res. Lett. 2018, 45(11): 5390-5397.
Yang, F., Ning, Z., Liu, H. Fractal characteristics of shales from a shale gas reservoir in the Sichuan Basin, China. Fuel 2014, 115: 378-384.
Yu, B., Cheng, P. A fractal permeability model for bi-dispersed porous media. Int. J. Heat Mass Transf. 2002, 45(14): 2983-2993.
Yu, B., Li, J. A geometry model for tortuosity of flow path in porous media. Chin. Phys. Lett. 2004, 21(8): 1569-1571.
Zhu, G., Kou, J., Yao, B., et al., Thermodynamically consistent modelling of two-phase flows with moving contact line and soluble surfactants. J. Fluid Mech. 2019, 879: 327-359.
Zuo, H., Deng, S., Li, H. Boundary scheme for lattice Boltzmann modeling of micro-scale gas flow in organic-rich pores considering surface diffusion. Chin. Phys. B 2019, 28(3): 030202.
Refbacks
- There are currently no refbacks.
Copyright (c) 2020 The Author(s)
This work is licensed under a Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International License.