1887

Abstract

Summary

Due to an increase of frontier exploration in the Campeche basin, southern Gulf of Mexico, the demands for basin scale integration for direct hydrocarbon prospectivity and seismic imaging were boosted. We carried out a regional rock physics analysis in the Campeche basin. The log data from more than 100 wells was analyzed to obtain transforms between mud rock properties such as P-wave velocity, density, pressure, temperature, and additionally, reservoir rock properties such as clay content, porosity, Poisson’s ratio, and fluids’ bulk modulus and density. These transforms were calibrated using available Petrophysical edited log data. The impact of fluid properties on AVO signature are modeled based on in-situ reservoir parameters such as pressure, temperature and gas oil ratio. Oil or gas-saturated reservoir sands show strong Poisson’s ratio anomaly compared to a modeled water-sand Poisson’s ratio. This suggests that Poisson’s ratio anomaly can be used as a direct hydrocarbon indicator for Tertiary sands in the Campeche basin. The impact of fluid properties on Pimpedance and Poisson’s ratio are calibrated using more than 30 discovery wells. These calibrated relationships between fluid properties and Poisson’s ratio can be used as a guidance to constrain AVO inversion for better pore fluids discrimination in this region.

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/content/papers/10.3997/2214-4609.202187001
2021-12-01
2024-10-05
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