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Study on the Propagation Law of COsub.2 Displacement in Tight Conglomerate Reservoirs in the Mahu Depression, Xinjiang, China
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Study on the Propagation Law of COsub.2 Displacement in Tight Conglomerate Reservoirs in the Mahu Depression, Xinjiang, China
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Journal Article
Study on the Propagation Law of COsub.2 Displacement in Tight Conglomerate Reservoirs in the Mahu Depression, Xinjiang, China
2025
Overview
To achieve the efficient utilization of low-permeability tight sand and gravel reservoirs with strong heterogeneity in the Mahu oil area of Xinjiang, CO[sub.2] injection is used to improve oil recovery. The sweep pattern of the injected gas is closely related to the development of reservoir pores and throats. Firstly, a three-dimensional model of the average pore-throat radius was established based on complete two-dimensional nuclear magnetic resonance scanning data of the target layer’s full-diameter core in the Wuerhe Formation. Subsequently, an online NMR injection CO[sub.2] continuous oil displacement experiment was conducted using tight conglomerate rock cores to clarify the rules of CO[sub.2] oil displacement in each pore-throat interval. Finally, the three-dimensional pore-throat model was combined with microscopic utilization patterns to quantitatively characterize the reservoir utilization rate of the CO[sub.2] displacement oil and guide on-site dynamic analysis. The research results indicate that the reservoir space of the Wuerhe Formation is mainly composed of residual intergranular pores, accounting for 40.9% of the pores, followed by intragranular dissolution pores and shrinkage pores. The proportion of pore-throat coordination numbers less than 1 is relatively high, reaching 86.3%. The average pore-throat radius calculation model, established using online NMR data from the continuous coring of full-diameter cores, elucidates the characteristics of the average pore-throat radius in the Wuerhe Formation reservoir. Based on gas displacement experiments that explored the pore-throat behavior at the microscale, the calibrated CO[sub.2] injection oil recovery rate was determined to be 43.9%, and the proportion of reserves utilized within the main range during CO[sub.2] displacement amounted to 60.77%. The injection pressure is negatively correlated with the maximum pore-throat radius of the gas injection well group, and negatively correlated with the proportion of the 0.9~2 μm distribution of large pore throats in each gas injection well group.
Publisher
MDPI AG
Subject
