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Pore-type identifcation of a heterogeneous carbonate reservoir using rock physics principles: a case study from south-west Iran

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Emami N. M. , Mehmandoost F. , Nosrati H.

Acta Geophysica

2021

tom Vol. 69, no. 4

1241--1256

The characterization of carbonate rocks is a challenging process compared to siliciclastics because of their more intricate pore-space structure. In this study, we applied rock physics methods to a heterogeneous carbonate reservoir located in southwest Iran to identify zones of various pore types, including inter-particle pores, stif (vuggy and moldic) pores, and cracks, from geophysical measurements. We frst constructed two rock physics templates (RPTs) using well logs and used them to quantitatively analyze the efect of various pore types on elastic properties. Using these RPTs, we then implemented an inversion algorithm to estimate the volume fractions of various pores using total porosity and P-wave velocity (Vp) derived from well logs. Next, we have compared the pore-type inversion results and the image log interpretation/core images at the corresponding depth intervals to validate inversion results. This comparison showed that the inversion results are consistent with the measurements. Also, we applied the introduced pore-type inversion algorithm on seismic data to achieve insight into pore-type distribution in the 3D framework of the reservoir under study. The results of these rock physics-based analyses indicate that the inter-particle pores are dominant in the pore-space, while there are stif pores and dispersal cracks in some subzones of the studied depth interval. Additionally, employing the Xu and Payne rock physics modeling procedure, P- and S-wave velocities were estimated using pore-type inversion results at the location of several wells from the studied feld. The calculated mean absolute error and the correlation coefcient indicate a high consistency between the measured and modeled velocities. This research may contribute to permeability prediction and analysis of the diagenetic processes’ impact on reservoir properties.

Prediction of porosity and gas saturation for deep‑buried sandstone reservoirs from seismic data using an improved rock‑physics model

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Yaneng L. , Handong H. , Morten J. , Yadi Y. , Jinwei Z. , Yanjie C.

Acta Geophysica

2019

tom Vol. 67, no. 2

557--575

In recent years, many important discoveries have been made in global deep oil and gas exploration, which indicates that deep exploration has gradually become one of the most important areas in current and future hydrocarbon exploration. However, the prediction of deep reservoirs is very challenging due to their low porosity and complex pore structure characteristics caused by the burial depth and diagenesis. Rock physics provides a link between the geologic reservoir parameters and seismic elastic properties and has evolved to become a key tool of quantitative seismic interpretation. Based on the mineral component and pore structure analysis of studied rocks, we propose an improved rock-physics model by introducing a third feldspar-related pore for deep-buried sandstone reservoirs to the traditional Xu–White model. This modelling process consists of three steps: first, rock matrix modelling using time-average equations; second, dry rock modelling using a multipore analytical approximation; and third, fluid-saturated rock modelling using a patchy distribution. It has been used in total porosity estimation, S-wave velocity prediction and rock-physics template establishment. The applicability of the improved rock-physics model is verified by a theoretical quartz-water model test and a real data total porosity estimation compared with the traditional Xu–White model and the density method. Then, a rock-physics template is generated by the improved rock-physics model for porosity and gas saturation prediction using seismic data. This template is carefully calibrated and validated by well-log data at both the well-log scale and seismic scale. Finally, the feasibility of the established rock-physics template for porosity and gas saturation prediction is validated by a deep-buried sandstone reservoir application in the East China Sea.