Complex Carbonate Rock Typing and Saturation Modeling with Highly-Coupled Geological Description and Petrophysical Properties
- Ebtesam BinAbadat (ADNOC Offshore) | Hani Bu-Hindi (ADNOC Offshore) | Omar Al-Farisi (ADNOC Offshore) | Atul Kumar (ADNOC Offshore) | Kamel Zahaf (ADNOC Offshore) | Loay Ibrahim (ADNOC Offshore) | Yaxin Liu (ADNOC Offshore) | Christophe Darous (Schlumberger Oil Company) | Luisa Barillas (Schlumberger Oil Company)
- 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
- Petrophysical Properties, Saturation Modeling, Rock Typing, Geological Description, Complex Carbonate
- 1 in the last 30 days
- 107 since 2007
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Reservoir Rock Typing and saturation modeling need a two-sided methodology. One side is the geological side of the rock types to populate properties within geological concepts. The other side is addressing reservoir flow and dynamic initialization with capillary pressure. The difficulty is to comply with both aspects especially in carbonates reservoirs with complex diagenesis and migration history. The objective of this paper is to describe the methodology and the results obtained in a complex carbonate reservoir.
The approach is initiated from the sedimentological description from cores and complemented with microfacies from thin sections. The core-based rock types use the dominant rock fabrics, as well as the cementation and dissolution diagenetic processes. The groups are limited to similar pore throat size distribution and porosity-permeability relationships to stay compatible with property modeling at a later stage.
At log-scale, the rock typing has a focus on the estimation of permeability using the most appropriate logs available in all wells. Those logs are porosity, mineral volumes, normalized saturation in invaded zone (Sxo), macro-porosity from borehole image or Nuclear Magnetic Resonance (NMR), NMR T2 log mean relaxation, and rigidity from sonic logs. A specific calculation to identify the presence of tar is also included to assess the permeability better and further interpret the saturation history. The MICP data defined the saturation height functions, according to the modality of the pore throat size. The log derived saturation, and the SHFs are used to identify Free Water Level (FWL) positions and interpret the migration history.
The rock typing classification is well connected with the geological aspects of the reservoirs since it originates from the sedimentological description and the diagenetic processes. We identified a total of 21 rock types across all the formations of interest. We associated rock types with depositional environments ranging from supra-tidal to open marine that controls both the original rock fabrics and the diagenetic processes. The rock typing classification is also appropriate to model permeability and saturation since core petrophysical measurements were in use during the classification. The permeability estimation from logs uses multivariate regressions that have proven to be sensitive to permeability after a Principal Component Analysis per zones and per lithologies. The difference between the core permeability and the permeability derived from logs stays within one-fold of standard deviation as compared to the initial 3-fold range of porosity-permeability. We assigned the rock types with three Saturation Height Function (SHF) classes; (unimodal-dolomite, unimodal- limestone & Multimodal-Limestone). The log derived water saturation (Sw) from logs and SHF shows acceptable agreement.
The reservoir rock typing and saturation modeling methodology described in this paper are considerate of honoring geological features and petrophysical properties to solve for complex diagenesis and post-migration fluid alteration and movement processes.
|File Size||2 MB||Number of Pages||18|
Lindsay, R.F.,Cantrell, D.L.,. Hughes, G.W.,Keith, T.H.,Mueller, H.W., III and Russell, S. D., 2006, Ghawar Arab-D Reservoir: Widespread porosity in shoaling-upward carbonate cycles, Saudi Arabia, in P.M. harris and L.J. Weber, eds., Giant Hydrocarbon reservoirs of the word: From rocks to reservoir characterization and modeling: AAPG Memoir88/SEPM Special Publication, p.97–137.
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