The selection of drilling fluid model has a significant impact on the efficiency of the initial opening of productive formations by drilling. There are two main models described in the literature. The first model is a drilling fluid that qualitatively seal formation pores, decreasing the area of degraded reservoir properties. The second model is characterized by deeper penetration into the reservoir without causing significant degradation of its properties. In the development and testing of drilling fluids, the criterion for maintaining the reservoir properties is the coefficient, obtained by comparing cores permeability measurements before and after the flooding experiments. Calcium carbonate is often used to prevent penetration of drilling fluid and its filtrate into the reservoir. However, in the case of application in emulsion drilling fluid when drilling wells where perforation is not provided, additional work is often required to restore hydrodynamic communication with the formation. Therefore, research on sealing properties of emulsion drilling fluid, including necessity of bridging agent, is relevant. On that purpose, a laboratory study on the sealing pores ability of the emulsion drilling fluid formulation developed for drilling wells in Eastern Siberia, and its effect on the core permeability coefficient was carried out. The results of the study showed that the characteristic high sealing pores ability is provided by the composition of the mud, taking into account the composition and properties of the reservoir and a solid phase, and the use of calcium carbonate in the developed drilling fluid is not advisable.
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