Quantitative Petrophysical Characterization of Reservoir Heterogeneity Using Dykstra–Parsons, Lorenz Coefficient, and Reservoir Quality Index Methods

Authors

• Fathi Khaleel Saleh Abdul Wahab, Research Scholar, Reservoir Simulation Laboratory, Petroleum Engineering Division, Department of Ocean Engineering, Indian Institute of Technology Madras, Chennai, Tamil Nadu-600036, IndiaFollow
• Suresh Kumar Govindarajan, Professor, Reservoir Simulation Laboratory, Petroleum Engineering Division, Department of Ocean Engineering, Indian Institute of Technology Madras, Chennai, Tamil Nadu-600036, India

Article Type

Research Paper

Corresponding Author

Fathi Khaleel Saleh Abdul Wahab

Highlights

• Quantitative petrophysical metrics provide a systematic approach to characterize reservoir heterogeneity.

• Integrated heterogeneity analysis reveals strong variations in permeability and flow-capacity distribution.

• Pore-throat quality significantly influences hydraulic connectivity and effective reservoir drainage.

• Heterogeneity controls preferential flow, compartmentalization, and the distribution of remaining hydrocarbons.

• Integrated petrophysical indicators identify poorly drained zones within mature sandstone reservoirs.

• The proposed workflow provides a transferable framework for reservoir characterization and development planning.

Abstract

Accurate characterization of reservoir heterogeneity is essential for evaluating remaining hydrocarbon resources and planning effective Reservoir development in mature sandstone reservoirs. This technical note presents a quantitative petrophysical evaluation of the Alif and Sean sandstone members in the Wadi Bana Field, Sab'atayn Basin, Yemen, using the Dykstra–Parsons coefficient (VDP) and Lorenz coefficient (LC) to evaluate reservoir heterogeneity, together with the Reservoir Quality Index (RQI) to assess pore-throat quality and flow characteristics. Petrophysical data derived from well logs and core analyses were integrated into a three-dimensional geological model to evaluate reservoir heterogeneity and quality. VDP values of 0.63 (Alif) and 0.78 (Sean) confirm moderate to strong vertical permeability variability, while LC values of 0.49 and 0.67 indicate highly uneven flow-capacity distribution. RQI values ranging from 1.0–1.4 µm (Alif) and 0.3–0.6 µm (Sean) indicate contrasting pore-throat quality between the two reservoir members. These results, combined with compartmentalization index analysis, identify two poorly connected zones near wells WB-14, WB-6 and WB-16 exhibiting current oil saturation exceeding 58–60% and retained reservoir pressure of 700–1,100 psi. The results demonstrate that permeability architecture and pore-throat quality exert primary control on drainage efficiency and remaining oil distribution. The quantitative workflow presented here is directly transferable to analogous heterogeneous sandstone reservoirs in the Arabian Peninsula and beyond.

Keywords

Reservoir heterogeneity; Dykstra–Parsons coefficient; Lorenz coefficient; Reservoir Quality Index; Sab'atayn Basin; Compartmentalization

Recommended Citation

Abdul Wahab, Fathi Khaleel Saleh and Govindarajan, Suresh Kumar (2026) "Quantitative Petrophysical Characterization of Reservoir Heterogeneity Using Dykstra–Parsons, Lorenz Coefficient, and Reservoir Quality Index Methods," Egyptian Journal of Petroleum: Vol. 35 : Iss. 4 , Article 12.
Available at: https://doi.org/10.62593/2090-2468.1138

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