Pore-scale study of the pressure-sensitive effect of sandstone and its influence on multiphase flows
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摘要
The pressure-sensitive effect on the pore structure of sandstone was investigated using X-ray computed micro-tomography and QEMSCAN quantitative mineral analysis. In a physical simulation study, we extracted the pore network model from digital cores at different confining pressures and evaluated the effect of pressure sensitivity on the multiphase displacement process. In both the pore network model and QEMSCAN scanning, the pore structure was observed to be damaged under a high confining pressure. Due to their different scales, the pores and throats exhibited inhomogeneous changes; further, the throats exhibited a significant variation compared to that exhibited by the pores. Meanwhile, the heterogeneity of the pore structure under the two aforementioned activities was aggravated by the elastic-plastic deformation of the pore structure.The pressure-sensitive effect increased the proportion of mineral particles, such as quartz(the main component of the core skeleton), and reduced the proportion of clay minerals. The clay minerals were originally attached to the pore walls or interspersed in the pores; however, as the pressure increased, the clay minerals accumulated in the pores resulting in blockage of the pores. While simulating the multiphase displacement process, increasing the confining pressure was observed to severely restrict the flowability of oil and water. This study promises to improve the efficiency of reservoir development in terms of oil and gas exploitation.
The pressure-sensitive effect on the pore structure of sandstone was investigated using X-ray computed micro-tomography and QEMSCAN quantitative mineral analysis. In a physical simulation study, we extracted the pore network model from digital cores at different confining pressures and evaluated the effect of pressure sensitivity on the multiphase displacement process. In both the pore network model and QEMSCAN scanning, the pore structure was observed to be damaged under a high confining pressure. Due to their different scales, the pores and throats exhibited inhomogeneous changes; further, the throats exhibited a significant variation compared to that exhibited by the pores. Meanwhile, the heterogeneity of the pore structure under the two aforementioned activities was aggravated by the elastic-plastic deformation of the pore structure.The pressure-sensitive effect increased the proportion of mineral particles, such as quartz(the main component of the core skeleton), and reduced the proportion of clay minerals. The clay minerals were originally attached to the pore walls or interspersed in the pores; however, as the pressure increased, the clay minerals accumulated in the pores resulting in blockage of the pores. While simulating the multiphase displacement process, increasing the confining pressure was observed to severely restrict the flowability of oil and water. This study promises to improve the efficiency of reservoir development in terms of oil and gas exploitation.
The pressure-sensitive effect on the pore structure of sandstone was investigated using X-ray computed micro-tomography and QEMSCAN quantitative mineral analysis. In a physical simulation study, we extracted the pore network model from digital cores at different confining pressures and evaluated the effect of pressure sensitivity on the multiphase displacement process. In both the pore network model and QEMSCAN scanning, the pore structure was observed to be damaged under a high confining pressure. Due to their different scales, the pores and throats exhibited inhomogeneous changes; further, the throats exhibited a significant variation compared to that exhibited by the pores. Meanwhile, the heterogeneity of the pore structure under the two aforementioned activities was aggravated by the elastic-plastic deformation of the pore structure.The pressure-sensitive effect increased the proportion of mineral particles, such as quartz(the main component of the core skeleton), and reduced the proportion of clay minerals. The clay minerals were originally attached to the pore walls or interspersed in the pores; however, as the pressure increased, the clay minerals accumulated in the pores resulting in blockage of the pores. While simulating the multiphase displacement process, increasing the confining pressure was observed to severely restrict the flowability of oil and water. This study promises to improve the efficiency of reservoir development in terms of oil and gas exploitation.
引文
An S,Yao J,Yang Y,Zhang L,Zhao J,Gao Y. Influence of pore structure parameters on flow characteristics based on a digital rock and the pore network model. J Nat Gas Sci Eng.2016;36(Part A):156-63. https://doi.org/10.1016/j.jngse.2016.03.009.
Andrew M, Bijeljic B, Blunt MJ. Pore-scale contact angle measurements at reservoir conditions using X-ray microtomography.Adv Water Resour. 2014a;68(2):24-31. https://doi.org/10.1016/j.advwaters.2014.02.014.
Andrew M, Bijeljic B,Blunt MJ. Pore-scale imaging of trapped supercritical carbon dioxide in sandstones and carbonates. Int J Greenh Gas Control. 2014b;22(2):1-14. https://doi.org/10.1016/j.ijggc.2013.12.018.
Andrew M, Menke H, Blunt MJ, Bijeljic B. The imaging of dynamic multiphase fluid flow using synchrotron-based X-ray microtomography at reservoir conditions. Transp Porous Media.2015;110(1):1-24. https://doi.org/10.1007/s11242-015-0553-2.
Biot MA,Willis DG. The elastic coefficients of the theory of consolidation. J Appl Mech. 1957;24:594-601.
Blunt MJ. Physically-based network modeling of multiphase flow in i ntermedi ate-wet porous media. J Pet Sci Eng.1998;20(3-4):117-25. https://doi.org/10.1016/S0920-4105(98)00010-2.
Buades A,Coll B, Morel JM. A non-local algorithm for image denoising. IEEE Comput Soc Conf Comput Vis Pattern Recognit. 2005;2(7):60-5.
Cai Y,Liu D,Mathews JP, Pan Z,Elsworth D,Yao Y,et al.Permeability evolution in fractured coal:combining triaxial confinement with X-ray computed tomography, acoustic emission and ultrasonic techniques. Int J Coal Geol.2014;122:91-104. https://doi.org/10.1016/j.coal.2013.12.012.
Cheng Y, Wu B, Li N, Yuan Z, Xu T. Research into the propagation of hydraulic fractures under coal-bed stress sensitivity. J China Coal Soc. 2013;38(9):1634-9(in Chinese).
Dong H, Blunt MJ. Pore-network extraction from micro-computerized-tomography images. Rev E Stat Nonlinear Soft Matter Phys. 2009;80(2):36-7. https://doi.org/10.1103/PhysRevE.80.036307.
Fang W,Jiang H,Li J,Li W,Li J,Zhao L,et al. A new experimental methodology to investigate formation damage in clay-bearing reservoirs. J Pet Sci Eng. 2016;143:226-34. https://doi.org/10.1016/j.petrol.2016.02.023.
Fatt I. The network model of porous media I. Capillary pressure characteristics. Pet Trans. 1956a;207:144-59.
Fatt I. The network model of porous mediaⅡ. Dynamic properties of a single size tube network. Pet Trans. 1956b;207:160-3.
Fatt I. The network model of porous mediaⅢ. Dynamic properties of networks with tube radius distributions. Pet Trans.1956c;207:164-81.
Feng Q,Liu Q,Li H,Zhang J,Tao H,Luo Y. Effect of permeability stress sensitivity on gas-water well productivity. J Pet Technol.2013;20(1):89-91(in Chinese).
Geertsma J. The effect of fluid pressure decline on volumetric changes of porous rocks. Trans Soc Pet Eng. 1957;210:331-40.
Hall HN. Compressibility of reservoir rocks. J Pet Technol.1953;5(1):17-9.
Huang X, Li J, Lei D, Qi Z, Yue X. Influence of stress sensitivity on gas well productivity for low permeability gas reservoirs. Fault Block Oil Gas Field. 2014;21(6):786-9(in Chinese).
Iglauer S, Lebedev M. High pressure-elevated temperature X-ray micro-computed tomography for subsurface applications. AdvColloid Interface Sci. 2017;256:393-410. https://doi.org/10.1016/j.cis.2017.12.009.
Iglauer S, Paluszny A, Pentland CH, Blunt MJ. Residual CO2 imaged with X-ray micro-tomography. Geophys Res Lett.2011;38(21):1440-1. https://doi.org/10.1029/2011GL049680.
Lebedev M, Zhang Y, Mikhaltsevitch V, Inglauer S, Rahman T.Residual trapping of supercritical CO2:direct pore-scale observation using a low cost pressure cell for micro computer tomography. Energy Procedia. 2017a;114:4967-74. https://doi.org/10.1016/j.egypro.2017.03.1639.
Lebedev M, Zhang Y, Sarmadivaleh M, Barifcani A, Al-Khdheeawi E, Iglauer S. Carbon geosequestration in limestone:pore-scale dissolution and geomechanical weakening. Int J Greenh Gas Control. 2017b;66:106-19. https://doi.org/10.1016/j.ijggc.2017.09.016.
Li C, Tu X. Two types of stress sensitivity mechanisms for reservoir rocks:being favourable for oil recovery. Lithol Reserv.2008;20(1):111-3(in Chinese).
Li R, Gao Y, Yang Y, Li Y, Yao J. Experimental study on the pressure sensitive effects of cores based on CT scanning. Pet Drill Tech. 2015;43(5):37-43(in Chinese).
Ma K, Jiang H, Li J, Zhao L. Experimental study on the micro alkali sensitivity damage mechanism in low-permeability reservoirs using QEMSCAN. J Nat Gas Sci Eng. 2016;36:1004-17. https://doi.org/10.1016/j.jngse.2016.06.056.
McLatchie AS, Hemstock RA, Young JW. The effective compressibility of reservoir rock and its effects on permeability. J Pet Technol. 1958; 10(6):49-51. https://doi.org/10.2118/894-G.
Oren PE, Bakke S. Reconstruction of Berea sandstone and pore-scale modelling of wettability effects. J Pet Sci Eng.2003;39(3-4):177-99. https://doi.org/10.1016/S0920-4105(03)00062-7.
Sheppard AP, Sok RM, Averdunk H. Improved pore network extraction methods. Proc Int Symp Soc Core Anal.2005;20:21-5.
Shi Y, Sun X. Stress sensitivity analysis of the Changqing tight clastic reservoir. Pet Explor Dev. 2001;5:85-7(in Chinese).
Silin DB, Jin G, Patzek TW. Robust determination of the pore space morphology in sedimentary rocks. In:Proceedings of the SPE annual technical conference and exhibition. Society of Petroleum Engineers of AIME; 2003. p. 2135-49.
Valvatne PH, Blunt MJ. Predictive pore-scale modelling of two-phase flow in mixed wet media. Water Resour Res. 2004;40(7):187.https://doi.org/10.1029/2003WR002627.
Wang J,Liu H, Liu R,Xu J. Numerical simulation for lowpermeability and extra-low permeability reservoirs considering starting pressure and stress sensitivity effects. Chin J Rock Mech Eng. 2013;32(2):3317-27(in Chinese).
Xie Y, Chen Z. Experiment study of permeability sensitivity in a loose sandstone gas reservoir. Fault Block Oil Gas Field.2013;20(4):488-91(in Chinese).
Yao J, Tao J, Li A. Research on oil-water two-phase flow using a 3D random network model. Acta Pet Sin. 2007;28(2):94-7(in Chinese).
Yang Y, Liu Z, Sun Z, An S, Zhang W, Liu P, et al. Research on stress sensitivity of fractured carbonate reservoirs based on CT technology. Energies. 2017;10(11):1833. https://doi.org/10.3390/en10111833.
Zhang Y,Xu X,Lebedev M,Sarmadivaleh M,Barifcani A,Iglauer S.Multi-scale X-ray computed tomography analysis of coal microstructure and permeability changes as a function of effective stress. Int J Coal Geol. 2016a;65:149-56. https://doi.org/10.1016/j.coal.2016.08.016.
Zhang Y,Lebedev M,Sarmadivaleh M,Barifcani A,Iglauer S.Swelling-induced changes in coal microstructure due to supercritical CO2 injection. Geophys Res Lett.2016b;43(17):9077-83. https://doi.org/10.1002/2016GL070654.
Zhang Y, Lebedev M, Al-Yaseri A, Yu H, Nwidee LN, Sarmadivaleh M,et al. Morphological evaluation of heterogeneous oolitic limestone under pressure and fluid flow using X-ray microtomography. J Appl Geophys. 2018;150:172-81. https://doi.org/10.1016/j.jappgeo.2018.01.026.
Andrew M, Bijeljic B, Blunt MJ. Pore-scale contact angle measurements at reservoir conditions using X-ray microtomography.Adv Water Resour. 2014a;68(2):24-31. https://doi.org/10.1016/j.advwaters.2014.02.014.
Andrew M, Bijeljic B,Blunt MJ. Pore-scale imaging of trapped supercritical carbon dioxide in sandstones and carbonates. Int J Greenh Gas Control. 2014b;22(2):1-14. https://doi.org/10.1016/j.ijggc.2013.12.018.
Andrew M, Menke H, Blunt MJ, Bijeljic B. The imaging of dynamic multiphase fluid flow using synchrotron-based X-ray microtomography at reservoir conditions. Transp Porous Media.2015;110(1):1-24. https://doi.org/10.1007/s11242-015-0553-2.
Biot MA,Willis DG. The elastic coefficients of the theory of consolidation. J Appl Mech. 1957;24:594-601.
Blunt MJ. Physically-based network modeling of multiphase flow in i ntermedi ate-wet porous media. J Pet Sci Eng.1998;20(3-4):117-25. https://doi.org/10.1016/S0920-4105(98)00010-2.
Buades A,Coll B, Morel JM. A non-local algorithm for image denoising. IEEE Comput Soc Conf Comput Vis Pattern Recognit. 2005;2(7):60-5.
Cai Y,Liu D,Mathews JP, Pan Z,Elsworth D,Yao Y,et al.Permeability evolution in fractured coal:combining triaxial confinement with X-ray computed tomography, acoustic emission and ultrasonic techniques. Int J Coal Geol.2014;122:91-104. https://doi.org/10.1016/j.coal.2013.12.012.
Cheng Y, Wu B, Li N, Yuan Z, Xu T. Research into the propagation of hydraulic fractures under coal-bed stress sensitivity. J China Coal Soc. 2013;38(9):1634-9(in Chinese).
Dong H, Blunt MJ. Pore-network extraction from micro-computerized-tomography images. Rev E Stat Nonlinear Soft Matter Phys. 2009;80(2):36-7. https://doi.org/10.1103/PhysRevE.80.036307.
Fang W,Jiang H,Li J,Li W,Li J,Zhao L,et al. A new experimental methodology to investigate formation damage in clay-bearing reservoirs. J Pet Sci Eng. 2016;143:226-34. https://doi.org/10.1016/j.petrol.2016.02.023.
Fatt I. The network model of porous media I. Capillary pressure characteristics. Pet Trans. 1956a;207:144-59.
Fatt I. The network model of porous mediaⅡ. Dynamic properties of a single size tube network. Pet Trans. 1956b;207:160-3.
Fatt I. The network model of porous mediaⅢ. Dynamic properties of networks with tube radius distributions. Pet Trans.1956c;207:164-81.
Feng Q,Liu Q,Li H,Zhang J,Tao H,Luo Y. Effect of permeability stress sensitivity on gas-water well productivity. J Pet Technol.2013;20(1):89-91(in Chinese).
Geertsma J. The effect of fluid pressure decline on volumetric changes of porous rocks. Trans Soc Pet Eng. 1957;210:331-40.
Hall HN. Compressibility of reservoir rocks. J Pet Technol.1953;5(1):17-9.
Huang X, Li J, Lei D, Qi Z, Yue X. Influence of stress sensitivity on gas well productivity for low permeability gas reservoirs. Fault Block Oil Gas Field. 2014;21(6):786-9(in Chinese).
Iglauer S, Lebedev M. High pressure-elevated temperature X-ray micro-computed tomography for subsurface applications. AdvColloid Interface Sci. 2017;256:393-410. https://doi.org/10.1016/j.cis.2017.12.009.
Iglauer S, Paluszny A, Pentland CH, Blunt MJ. Residual CO2 imaged with X-ray micro-tomography. Geophys Res Lett.2011;38(21):1440-1. https://doi.org/10.1029/2011GL049680.
Lebedev M, Zhang Y, Mikhaltsevitch V, Inglauer S, Rahman T.Residual trapping of supercritical CO2:direct pore-scale observation using a low cost pressure cell for micro computer tomography. Energy Procedia. 2017a;114:4967-74. https://doi.org/10.1016/j.egypro.2017.03.1639.
Lebedev M, Zhang Y, Sarmadivaleh M, Barifcani A, Al-Khdheeawi E, Iglauer S. Carbon geosequestration in limestone:pore-scale dissolution and geomechanical weakening. Int J Greenh Gas Control. 2017b;66:106-19. https://doi.org/10.1016/j.ijggc.2017.09.016.
Li C, Tu X. Two types of stress sensitivity mechanisms for reservoir rocks:being favourable for oil recovery. Lithol Reserv.2008;20(1):111-3(in Chinese).
Li R, Gao Y, Yang Y, Li Y, Yao J. Experimental study on the pressure sensitive effects of cores based on CT scanning. Pet Drill Tech. 2015;43(5):37-43(in Chinese).
Ma K, Jiang H, Li J, Zhao L. Experimental study on the micro alkali sensitivity damage mechanism in low-permeability reservoirs using QEMSCAN. J Nat Gas Sci Eng. 2016;36:1004-17. https://doi.org/10.1016/j.jngse.2016.06.056.
McLatchie AS, Hemstock RA, Young JW. The effective compressibility of reservoir rock and its effects on permeability. J Pet Technol. 1958; 10(6):49-51. https://doi.org/10.2118/894-G.
Oren PE, Bakke S. Reconstruction of Berea sandstone and pore-scale modelling of wettability effects. J Pet Sci Eng.2003;39(3-4):177-99. https://doi.org/10.1016/S0920-4105(03)00062-7.
Sheppard AP, Sok RM, Averdunk H. Improved pore network extraction methods. Proc Int Symp Soc Core Anal.2005;20:21-5.
Shi Y, Sun X. Stress sensitivity analysis of the Changqing tight clastic reservoir. Pet Explor Dev. 2001;5:85-7(in Chinese).
Silin DB, Jin G, Patzek TW. Robust determination of the pore space morphology in sedimentary rocks. In:Proceedings of the SPE annual technical conference and exhibition. Society of Petroleum Engineers of AIME; 2003. p. 2135-49.
Valvatne PH, Blunt MJ. Predictive pore-scale modelling of two-phase flow in mixed wet media. Water Resour Res. 2004;40(7):187.https://doi.org/10.1029/2003WR002627.
Wang J,Liu H, Liu R,Xu J. Numerical simulation for lowpermeability and extra-low permeability reservoirs considering starting pressure and stress sensitivity effects. Chin J Rock Mech Eng. 2013;32(2):3317-27(in Chinese).
Xie Y, Chen Z. Experiment study of permeability sensitivity in a loose sandstone gas reservoir. Fault Block Oil Gas Field.2013;20(4):488-91(in Chinese).
Yao J, Tao J, Li A. Research on oil-water two-phase flow using a 3D random network model. Acta Pet Sin. 2007;28(2):94-7(in Chinese).
Yang Y, Liu Z, Sun Z, An S, Zhang W, Liu P, et al. Research on stress sensitivity of fractured carbonate reservoirs based on CT technology. Energies. 2017;10(11):1833. https://doi.org/10.3390/en10111833.
Zhang Y,Xu X,Lebedev M,Sarmadivaleh M,Barifcani A,Iglauer S.Multi-scale X-ray computed tomography analysis of coal microstructure and permeability changes as a function of effective stress. Int J Coal Geol. 2016a;65:149-56. https://doi.org/10.1016/j.coal.2016.08.016.
Zhang Y,Lebedev M,Sarmadivaleh M,Barifcani A,Iglauer S.Swelling-induced changes in coal microstructure due to supercritical CO2 injection. Geophys Res Lett.2016b;43(17):9077-83. https://doi.org/10.1002/2016GL070654.
Zhang Y, Lebedev M, Al-Yaseri A, Yu H, Nwidee LN, Sarmadivaleh M,et al. Morphological evaluation of heterogeneous oolitic limestone under pressure and fluid flow using X-ray microtomography. J Appl Geophys. 2018;150:172-81. https://doi.org/10.1016/j.jappgeo.2018.01.026.