Wellbore Stability Mechanism of Fractured Formation in the Thrust Belt of Southern Margin of Junggar Basin

doi:10.11885/j.issn.1674-5086.2021.10.05.34

Abstract

Abstract: The southern margin of Junggar Basin is characterized by complex geological structure, fractured formation and poor drillability, and frequent lost circulation, tending to stick and collapse during drilling. In order to achieve safe drilling of fractured formation in the southern margin, the lithology, hydration and rock mechanics characteristics of the formation represented by Tugulu and Hutubi anticlines are studied, and the clay mineral content, hydration strength and compressive strength of different formation are compared. Combined with the seismic interpretation section and the compressive strength loss model, the mechanism of wellbore instability and the mechanism of drilling fluid stability in the fractured formation in the southern margin are analyzed. The results show that the southern margin of the formation is dominated by mudstone and sandstone, the whole rock minerals are dominated by clay minerals, plagioclase and quartz, and the clay minerals are dominated by illite and illite/smectite, and the hydration characteristics are highly heterogeneous, including extremely strong-weak dispersion and strong-medium-weak expansion. The hydration expansion and dispersion of clay minerals and the expansion and expansion of micro-pores and fractures in the fractured formation around the well lead to the decrease of formation compressive strength, the increase of collapse pressure, and the decrease of drilling fluid density window, leading to wellbore instability. Reasonable drilling fluid density, excellent hydration inhibition, comprehensive porosity sealing, strict high temperature and high pressure filtration and efficient lithology carrying are the necessary measures to achieve safe drilling and wellbore stability in the fractured formation in the southern margin. The research results can provide a reference for the design of key parameters of drilling fluids in deep complex fractured formations in the southern margin and even Junggar Basin.

Key words: Junggar Basin, southern margin, fractured formation, wellbore stability, drilling fluid

CLC Number:

TE254

YE Cheng, REN Tao, YIN Zebin, LI Cheng, BAI Yang. Wellbore Stability Mechanism of Fractured Formation in the Thrust Belt of Southern Margin of Junggar Basin[J]. Journal of Southwest Petroleum University(Science & Technology Edition), 2023, 45(6): 95-103.

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