This study investigates the GABO field in the onshore Niger Delta Basin using well logs and core samples, with a focus on rock type distribution, reservoir continuity, and petrophysical properties to enhance hydrocarbon exploration accuracy. The research involved detailed analysis of core descriptions and images from GABO-20, along with petrophysical data from wells GABO-4, GABO-12, GABO-13, GABO-20, and GABO-51, aiming to identify rock types, evaluate reservoir quality, and determine the spatial distribution of petrophysical properties. The methodology included rigorous well log quality checks, data correlation between wells, petrophysical property evaluation, and lithofacies description. The analysis revealed thirty-five hydrocarbon-bearing zones, with GABO-20 showing average shale fraction values between 0.111 and 0.335, total porosity ranging from 0.242 to 0.329, and hydrocarbon saturation from 0.667 to 0.923, indicating substantial porosity and hydrocarbon saturation conducive to extraction. Well correlations demonstrated excellent sand-shale continuity within the reservoir intervals. Lithofacies analysis of the GABO-20 core identified eight distinct facies, including shale poles, liquid-rich shales, and sandstone poles, revealing a complex distribution of reservoir qualities with significant variations in potential. Cores 1 and 2 exhibited favourable conditions for hydrocarbon production, while Core 3 showed lower reservoir quality due to increased clay content. The depositional settings of the GABO field, particularly in the lower delta plain and delta front zones, showed well-developed reservoir bodies with moderate potential in the tidal zone and little potential in the shaly prodelta environment. This distribution highlights the complexity of the deltaic system and its implications for reservoir modeling and utilization. Reservoir zones associated with High-Quality Reservoir Facies exhibited strong petrophysical properties, suggesting excellent hydrocarbon production potential. The study underscores the importance of detailed reservoir characterization to optimize recovery strategies, offering valuable insights into the distribution and quality of reservoir sands, reducing subsurface uncertainty, and emphasizing the integration of facies and petrophysical approaches for a better understanding of reservoir characteristics in the GABO field.
This article reviews and assesses the reservoir characteristics of several geologic Formations in the northeast of the Arabian plate, from the Permian–Triassic to Oligo-Miocene, and evaluates the complex interrelations between tectonic activities, paleoclimatic conditions and diagenetic alterations. All of these Formations have been deposited in a ramp depositional setting. Both dolomitization and dissolution diagenetic processes have significantly enhanced the reservoir quality by altering the porosity and permeability of the Permian–Triassic Kangan and the Dalan Formations. The diagenetic processes of dissolution, fracturing, and localized dolomitization have enhanced the reservoir properties of the Fahliyan Formation's carbonate sequence. The Cretaceous Dariyan exhibits a gradual facies transition where dissolution enhances reservoir quality, while cementation and compaction diminish reservoir properties. For the mid-Cretaceous Sarvak Formation, the investigation addressed the diagenetic history triggering the creation of secondary porosity, related to meteoric processes and karstification. Finally, the Oligo-Miocene Asmari Formation is presented as a major hydrocarbon reservoir with extensive carbonate facies. Tectonic-driven fracturing and faulting increased reservoir quality by altering primary porosity and permeability and inducing significant diagenetic changes within a complex biodiverse reef ecosystem. This paper aims to comprehensively review and analyze the interaction between facies, diagenesis, tectonic activities, and paleoclimate across several geological Formations in the study area. By synthesizing existing literature and conducting a comparative analysis, the study seeks to elucidate how these factors collectively influence reservoir properties and dynamics. This approach not only identifies current knowledge gaps but also provides insights into potential avenues for future research and scientific exploration.