Overpressure Generation and Evolution in Deep Longmaxi Formation Shale Reservoir in Southern Sichuan Basin: Influences on Pore Development

Jia Yin, Lin Wei (), Shasha Sun (), Zhensheng Shi, Dazhong Dong and Zhiye Gao
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Jia Yin: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Lin Wei: School of Energy Resources, China University of Geosciences, Beijing 100083, China
Shasha Sun: Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
Zhensheng Shi: Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
Dazhong Dong: Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
Zhiye Gao: State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum, Beijing 102249, China

Energies, 2023, vol. 16, issue 6, 1-25

Abstract: Strong overpressure conditions are widely distributed in the deep Longmaxi Formation (Fm) shale reservoirs in the Southern Sichuan Basin, with pressure coefficients ranging from 1.75 to 2.45. Overpressure plays a positive role in the high yield of shale gas, but a detailed study of its generation mechanism, evolution history, and potential impact on pore development is still lacking. This study’s evidence from theoretical analysis and the logging response method indicates that hydrocarbon generation expansion is the main generation mechanism for strong overpressure. Through the combined analysis of basin modeling, inclusions analysis, and numerical simulation, pressure evolution at different stages is quantitatively characterized. The results show that, during the shale’s long-term subsidence process, the shale reservoir’s pressure coefficient increased to 1.40 because of oil generated by kerogen pyrolysis. Then it increased to 1.92 due to gas generated by residual oil cracking. During the late strong uplift process of the shale, temperature decrease, gas escape, and stratum denudation caused the pressure coefficient to first decrease to 1.84 and then increased to 2.04. Comparing pore characteristics under different pressure coefficients indicates that higher pressure coefficients within shale reservoirs contribute to the maintenance of total porosity and the development of organic macropores, but the influence on the morphology of organic pores is negligible. These results will provide the scientific basis for optimizing sweet spots and guiding shale gas exploration in the study area.

Keywords: generation mechanism; overpressure evolution; numerical simulation; Longmaxi Formation shale (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2023
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