Investigating the Fluid–Solid Interaction of Acid Nonionic Nanoemulsion with Carbonate Porous Media

Abstract

The subject of rock–fluid interaction is important in cases where flow through porous media is occurring. One special case is when the fluid reacts with the porous matrix. In this case, the mass transfer and reaction rate control the dissolution pattern. This article aimed to study the interaction between an acid nanoemulsion system and a carbonate porous media. Nanoemulsions were developed to retard the rock’s dissolution and to promote the formation of conductivity channels. Nanoemulsions were prepared using ALK100 (alkyl alcohol ethoxylate) and RNX110 (alkylphenol ethoxylate) (nonionic surfactants), sec-butanol (co-surfactant), xylene isomers (oil phase), and a solution of HCl (aqueous phase). The obtained systems were characterized in terms of surface tension, droplet diameter, and reactivity. X-ray fluorescence/diffraction (XRF/XRD) and X-ray microtomography (microCT) were performed on carbonate porous media samples treated with the acid systems in order to observe the effects of the fluid–rock interaction. The results showed that the acid nanoemulsion, presenting a low oil content formulation, showed the low surface tension and droplet size characteristic of nanoemulsions. It was experimentally verified that the reactivity in the nanoemulsion media was mass-transfer-retarded, and that the wormhole pattern was verified under the studied conditions.

Experimental Investigation of the Impact of CO2 Injection Strategies on Rock Wettability Alteration for CCS Applications

“…These studies corroborate the se tivity of rock surface wettability to environmental conditions and fluid composition. F Similarly, Indiana limestone CA ranged from 77.6 to 87.9 • with an average of 83.6 • with a narrow variability, as indicated by a standard deviation of 2.80 • , which is slightly higher than the Berea sandstone, but still indicates a water-wet to intermediate-wet system, as shown in Table 2 2021) measured original and varying CAs in Indiana limestone using distilled and various saline waters, respectively [73,74], highlighting substantial variations dependent on the fluid medium. These studies corroborate the sensitivity of rock surface wettability to environmental conditions and fluid composition.…”

“…Pretest CA Mean ± STD (°) Post-Test CA Mean ± STD (°) 1L 86.3 ± 2.9 84.7 ± 2.9 87.9 ± 3.5 100.3 ± 0.9 100.9 ± 0.8 99.6 ± 1 2L 85.9 ± 0.5 83.9 ± 0.4 87.9 ± 0. 2021) measured original and varying CAs in Indi limestone using distilled and various saline waters, respectively [73,74], highlighting s stantial variations dependent on the fluid medium. These studies corroborate the se tivity of rock surface wettability to environmental conditions and fluid composition.…”

Effects of Foam Microbubbles on Electrical Resistivity and Capillary Pressure of Partially Saturated Porous Media

“…For such reservoirs, enhanced or tertiary hydrocarbon recovery methods are being considered. Such methods include injection of gas or chemicals (e.g., surfactants, polymers, CO 2 ) to alter the surface tension [11,12], rock wettability, and capillary pressures. An effective alteration of the wettability and capillary pressures can significantly improve hydrocarbon recovery from tight reservoir pores that were initially un-swept during secondary recovery.…”