Geological models and controlling factors of gas content in marine–terrigenous shale in the Southern Qinshui Basin, China

Abstract

Geological prediction models for gas content in marine-terrigenous shale under the effects of reservoir characteristics and in situ geological conditions, were established using methane isothermal adsorption, high temperature/pressure methane isothermal adsorption, total organic carbon, X-ray diffraction, mercury porosimetry, porosity in net confining stress, and field desorption methods. Results indicated that the adsorption capacity of marine-terrigenous shale has a linearly positive correlation with total organic carbon content and maturity. Clay and quartz minerals are the two main components of inorganic minerals in marine-terrigenous shale, with an average content of 54.3% and 36.9%, respectively. Adsorption capacity of marine-terrigenous shale is slightly positive correlated with clay content, while it exponentially decreases with increasing quartz content. The effects of in situ temperature and reservoir pressure on adsorption capacity in marine-terrigenous shale are also significant. The adsorption capacity of marineterrigenous shale shows a clear decreasing trend as temperature increases, while it increases with increasing reservoir pressure. The porosity of marine-terrigenous shale is characterized by highly stress-sensitive, decreasing exponentially with increasing effective stress, which results in a more complex occurrence of free gas in deep shale reservoirs. In addition, gas saturation for the shale samples was calculated based on the results of field desorption, after which geological prediction models of total gas, adsorbed gas, and free gas were established while considering the coupled

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“…The shale gas in the Sichuan Basin is mainly adsorbed gas and free gas. , The vertical distribution of adsorbed gas in a shale reservoir is controlled mainly by the adsorption capacity of the organic matter and clay minerals in each shale gas interval. Shale with high organic content generally has a higher proportion of adsorbed gas. − Free gas exists mainly in large pores and microfractures in shale, and its quantity depends on the pore space in the shale. − Therefore, the proportion of free gas in a shale reservoir depends on the shale pore space.…”