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Summary One of the complications at the stage with steam injection start into the SAGD injection well in the Terrigenous reservoir with extra-heavy oil (EHO) is its injectivity rate. Traditionally, preheating the well bottom-hole (BH) zone with steam and subsequent recovery of hot water or steam through the annulus is used to get adequate injectivity. As an alternative to steam preheating it is proposed to inject an aromatic solvent/reagent to ensure sufficient well injectivity. Calculations were performed with the real reservoir model. The mutual influence of wells in SAGD blocks under the conditions of solvent/reagent injection was studied for this.

The paper presents various modified technologies to enhance oil production and to stimulate the inflow of high-viscosity oil, based on a combination of the traditional approach and the use of solvents. The results of laboratory experiments to study the effects of 29 solvents reagents on high-viscosity oil samples from 5 different objects are presented. Based on the analysis of the obtained laboratory data, basic recommendations are formulated to increase the efficiency of extraction of high-viscosity oil using solvents. In order to determine the potential for modifying oil recovery enhancement and well stimulation methods by adding solvents to their process, a comparative hydrodynamic modeling of 3 treatment options for the bottom-hole zone and subsequent assessment of their economic effect were carried out.