Geology-Based Porosity-Permeability Correlations in Carbonate Rock Types
- Moustafa Dernaika (ADNOC) | Shehadeh Masalmeh (ADNOC) | Bashar Mansour (Ingrain – Halliburton) | Osama Al Jallad (Ingrain – Halliburton) | Safouh Koronfol (Ingrain – Halliburton)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Characterisation and Simulation Conference and Exhibition, 17-19 September, Abu Dhabi, UAE
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Rock Type, Texture, Modeling, Carbonate, Permeability
- 5 in the last 30 days
- 198 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
In carbonate reservoirs, permeability prediction is often difficult due to the influence of various geological variables that control fluid flow. Many attempts have been made to calculate permeability from porosity by using theoretical and empirical equations. The suggested permeability models have been questionable in carbonates due to inherent heterogeneity and complex pore systems. The main objective of this paper is to resolve the porosity-permeability relationships and evaluate existing models for predicting permeability in different carbonate rock types.
Over 1000 core plugs were studied from 7 different carbonate reservoirs across the Middle East region; mainly cretaceous reservoirs. The plugs were carefully selected to represent main property variations in the cored intervals. The data set available included laboratory-measured helium porosity, gas permeability, thin-section photomicrographs and high-pressure mercury injection. Plug-scale X-ray CT imaging was acquired to ensure the samples were free of induced fractures and other anomalies that can affect the permeability measurement. Rock textures were analyzed in the thin-section photomicrographs and were classified based on their content as grainy, muddy and mixed. Special attention was given to the diagenesis effects mainly compaction, cementation and dissolution.
The texture information was plotted in the porosity-permeability domain, and was found to produce three distinct porosity-permeability relationships. Each texture gave unique poro-perm trend, where the extent of the trend was controlled by diagenesis. Rock types were defined on each trend by detailed texture analysis and capillary pressure. Three different permeability equations (Kozney, Winland, Lucia) were evaluated to study their effectiveness in complex carbonate reservoirs. A new permeability equation was proposed to enhance the prediction results of the experimental data.
Rock types were successfully classified based on porosity, permeability, capillarity and textural facies. Conclusive porosity-permeability relationships were obtained from textural rock properties and diagenesis, which were linked to rock types using capillary pressure. The texture-diagenesis based rock types provided more insight into the effects of geology on fluid flow and saturation. Available models may not fully describe permeability in heterogeneous rocks but they can improve our understanding of fluid flow characteristics and predict permeability in un-cored wells.
|File Size||5 MB||Number of Pages||36|
Ambastha, A. K. and Moynihan, T. J. "A Simple And Accurate Method For An Integrated Analysis Of Core And Log Data To Describe Reservoir Heterogeneity" Petroleum Society of Canada. doi:10.2118/96-01-06 (1996)
Buiting, J.J.M., Clerke, E.A. "Permeability from porosimetry measurements: Derivation for a tortuous and fractal tubular bundle" J Petrol Sci Eng, (2013) http://dx.doi.org/10.1016/j.petrol.2013.04.016i
Dernaika, M., Al Mansoori, M., Singh, M., Al Dayyani, T., Kalam, Z., Bhakta, R., Koronfol, S., Naseer Uddin, Y., (2018) "Digital and Conventional Techniques to Study Permeability Heterogeneity in Complex Carbonate Rocks" PETROPHYSICS, VOL. 59, NO. 3 (June 2018); DOI: 10.30632/PJV59N3-2018a6
Masalmeh, S. K., Wei, L., Hillgartner, H., Al-Mjeni, R., & Blom, C. P. A. (2012, January 1). Developing High Resolution Static and Dynamic Models for Waterflood History Matching and EOR Evaluation of Giant Middle Eastern Carbonate Reservoir. Society of Petroleum Engineers. doi:10.2118/161485-MS