Micro-scale experimental investigation of the effect of flow rate on trapping in sandstone and carbonate rock samples. (August 2016)

• Record Type: Journal Article
• Authors: Khishvand, Mahdi; Akbarabadi, Morteza; Piri, Mohammad
• Is Part Of: Advances in water resources. Volume 94(2016)
• Page Start: 379
• Page End: 399
• Publication Date: 2016-08
• Subjects: Micro-CT imaging -- Pore-scale displacement mechanisms -- Miniature core-flooding experiments -- Dynamic flow regime -- Contact angle -- Matrix dissolution; Hydrology -- Periodicals; Hydrodynamics -- Periodicals; Hydraulic engineering -- Periodicals; 551.48
• DOI: 10.1016/j.advwatres.2016.05.012
• Languages: English
• ISSNs: 0309-1708

Abstract

Highlights: A μ -CT integrated with a core-flooding setup was used to perform flow experiments on two samples. The CT images provided direct observation of pore-fluid occupancies and displacement mechanisms. Trapped oil saturation decreased significantly during viscous-dominated imbibition tests. Statistical and geometrical techniques were used to perform cluster analysis. Contact angle hysteresis was studied using the micro-CT images. The impact of very high brine flow rate on the pore-matrix structure of limestone core was explored. Abstract: We present the results of a pore-scale experimental study of residual trapping in consolidated sandstone and carbonate rock samples under confining stress. We investigate how the changes in wetting phase flow rate impacts pore-scale distribution of fluids during imbibition in natural, water-wet porous media. We systematically study pore-scale trapping of the nonwetting phase as well as size and distribution of its disconnected globules. Seven sets of drainage-imbibition experiments were performed with brine and oil as the wetting and nonwetting phases, respectively. We utilized a two-phase miniature core-flooding apparatus integrated with an X-ray microtomography system to examine pore-scale fluid distributions in small Bentheimer sandstone (D = 4.9 mm and L = 13 mm) and Gambier limestone (D = 4.4 mm and L = 75 mm) core samples. The results show that with increase in capillary number, the residual oil saturation at the end of the imbibition reduces from 0.46 to 0.20 in Bemtheimer sandstone and from 0.46 to 0.28 in Gambier limestone. We use pore-scale displacement mechanisms, in-situ wettability characteristics, and pore size distribution information to explain the observed capillary desaturation trends. The reduction was believed to be caused by alteration of the order in which pore-scale displacements took place during imbibition. Furthermore, increase in capillary number produced significantly different pore-scale fluid distributions during imbibition. We explored the pore fluid occupancies and studied size and distribution of the trapped oil clusters during different imbibition experiments. The results clearly show that as the capillary number increases, imbibition produces smaller trapped oil globules. In other words, the volume of individual trapped oil globules decreased at higher brine flow rates. Finally, we observed that the pore space in the limestone sample was considerably altered through matrix dissolution at extremely high brine flow rates. This increased the sample porosity from 44% to 62% and permeability from 7.3 D to 80 D. Imbibition in the altered pore space produced lower residual oil saturation (from 0.28 to 0.22) and significantly different distribution of trapped oil globules.