气候变化领域集成服务门户(CCPortal): CO2-brine relative permeability and capillary pressure of Tuscaloosa sandstone: Effect of anisotropy

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DOI	10.1016/j.advwatres.2019.103464
	CO2-brine relative permeability and capillary pressure of Tuscaloosa sandstone: Effect of anisotropy
	Bakhshian S.; Hosseini S.A.; Lake L.W.
发表日期	2020
ISSN	0309-1708
卷号	135
英文摘要	Relative permeability and capillary pressure are known as essential properties that have substantial impacts on the accuracy of reservoir simulations. The effect of small-scale heterogeneity and lamination in the rock structure is often ignored during the measurement of capillary pressure and relative permeability curves in core samples. This study highlights the remarkable impact of anisotropy on the multiphase flow properties of stratified formations. A series of steady-state CO2-brine drainage and imbibition tests are conducted at reservoir conditions in horizontal and vertical core samples of the Tuscaloosa sandstone from the Cranfield CO2 injection site in Mississippi. The relative permeability curves represent an anisotropic behavior influenced by the heterogeneous and laminated structure of realistic rock samples. The CO2 saturation profiles during drainage and imbibition cycles indicate that the phase distribution in the pore space is controlled by core-scale heterogeneity in the porosity distribution among the laminations that causes capillary pressure inhomogeneity. Using the saturation profile during the imbibition cycle, the trapping characteristic of the horizontal and vertical rock samples are compared and we found that the capillary trapping is less likely in the vertical direction. Furthermore, the centrifuge-measured capillary pressure demonstrates distinctive characteristics for horizontal and vertical core samples. Since the flooding experiments are performed under capillary controlled flow, the capillary pressure contrast in the laminated structure of the rock strongly affects the relative permeability. The presented results can potentially improve the accuracy of the large-scale simulations for the CO2 post-injection period, in which the vertical displacement has an important role in the plume migration. © 2019 Elsevier Ltd
关键词	Anisotropy Capillarity Capillary tubes Carbon dioxide Floods Petroleum reservoir engineering Pressure effects Sandstone CO2 sequestration Core flooding Core-scale heterogeneities Large scale simulations Multi-phase flow properties Relative permeability Relative permeability curves Small-scale heterogeneity Core samples anisotropy brine capillary pressure carbon dioxide carbon sequestration imbibition multiphase flow permeability sandstone Cranfield Field Mississippi United States
语种	英语
来源机构	Advances in Water Resources
文献类型	期刊论文
条目标识符	http://gcip.llas.ac.cn/handle/2XKMVOVA/131893
推荐引用方式 GB/T 7714	Bakhshian S.,Hosseini S.A.,Lake L.W.. CO2-brine relative permeability and capillary pressure of Tuscaloosa sandstone: Effect of anisotropy[J]. Advances in Water Resources,2020,135.
APA	Bakhshian S.,Hosseini S.A.,&Lake L.W..(2020).CO2-brine relative permeability and capillary pressure of Tuscaloosa sandstone: Effect of anisotropy.,135.
MLA	Bakhshian S.,et al."CO2-brine relative permeability and capillary pressure of Tuscaloosa sandstone: Effect of anisotropy".135(2020).