Accurate rock grouping and permeability prediction in complex carbonate reservoirs are critical for adequate reservoir characterization and management. These reservoirs are often challenging due to the intricate interplay of sedimentary and diagenetic processes that influence pore geometry and rock properties. This study introduces a new approach to connect carbonate reservoirs' sedimentary and diagenetic features using a pore geometry structure rock typing method. The objective is to enhance rock grouping and improve permeability prediction. The implementation of basic PGS rock typing in this study follows the rock type curve established by Wibowo and Permadi (2013), which is based on the similarity of the Kozeny constant (Kozeny, 1927). This constant is calculated as the product of the pore shape factor (Fs) and tortuosity (τ) as a parametric variable within specific rock groups. This method allows for a systematic exploration of the critical factors governing multiphase flow behavior within porous rocks. The study analyzed data from four cored wells, totaling nearly 1650 feet, which included 1185 routine core analysis (RCA) samples, 440 mercury injection capillary pressure (MICP) samples, and thin section data. Our methodology integrates detailed petrographic analysis, sedimentological studies, and advanced pore geometry characterization. Combining these geological insights with quantitative Petrophysical Group (PG) data from Mercury Injection Capillary Pressure (MICP), we develop a rock typing framework that links pore structure variations to sedimentary and diagenetic controls, including cementation and dissolution processes. This enables the identification of distinct rock types that reflect depositional environments and diagenetic alterations, which directly influence reservoir quality and fluid flow. This approach's application as a new insight to complement the Pore Geometry Structure (PGS) rock typing method demonstrates its effectiveness in grouping reservoir rocks with similar permeability and fluid flow characteristics. Our findings show a clear and robust correlation between the dissolution process and pore geometry structure, providing a solid foundation for the methodology. This is an additional equation for quantitatively specific surface area in the porosity- permeability relationship. This updated pore geometry- structure rock typing method provides a more accurate and geologically informed basis for permeability prediction, contributing to better reservoir modeling in complex carbonate systems. This study presents a novel framework that bridges the gap between sedimentary and diagenetic features and their impact on pore structures. It offers valuable insights that could significantly influence future reservoir development strategies in similar carbonate environments.
Kusuma et al. (Sat,) studied this question.
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