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Collaborating Authors
Sinclair, Gary
Core Characterization and Numerical Flow Simulation in Representative Rock Types of the Raudhatain Field in Kuwait
Dernaika, Moustafa R (Ingrain Inc) | Sahib, Mohammad Raffi (Kuwait Oil Company) | Gonzalez, David (Ingrain Inc) | Mansour, Bashar (Ingrain Inc) | Al Jallad, Osama (Ingrain Inc) | Koronfol, Safouh (Ingrain Inc) | Sinclair, Gary (Ingrain Inc) | Kayali, Anas (Ingrain Inc)
Abstract Detailed core characterization is often overlooked in the sampling process for core analysis measurements. Random core sampling is usually performed and the selected plugs are not associated with rock types or the reservoir heterogeneity. The objective of this study is to obtain representative samples for direct simulation of petrophysical and fluid flow properties in complex rock types. A robust sampling strategy was followed in reservoir cores from two successive heterogeneous carbonate and siliciclastic formations in the Raudhatain field in Kuwait. The sample selection criteria were based on statistical distribution of litho-types in the cores to ensure optimum characterization of the main reservoir units. The litho-types were identified based on porosity and mineralogy variations along the core lengths utilizing advanced dual-energy X-ray CT scanning. High resolution micro-CT imaging and subsequent segmentation provided 3D representation of the pore space and geometric fabric of the core samples. Primary drainage and imbibition processes were simulated in numerical experiments using a pore-scale simulator by the Lattice Boltzmann Method. Capillary pressure (Pc) and relative permeability (Kr) curves together with water and oil distributions were investigated for complex geometries by the different rock types. The dual energy CT density was compared with wireline log and provided accurate calibrations to the downhole logs. The different rock types gave distinct capillary and flow properties that can be linked to the rock structure and pore type of the samples. The Lattice Boltzmann based pore-level fluid calculations provided realistic fluid distributions in the 3D rock volume, which are consistent with pore-scale physical phenomena. This characterization method by the dual energy CT eliminates sampling bias and allows for each cored litho-type to be equally represented in the plugs acquired for subsequent petrophysical and fluid flow analyses. It also provides accurate calibration tool for downhole logs. The digital analysis gave reliable SCAL data with improved understanding of the pore-level events and proved its effectiveness in providing advanced interpretations at multiple scales in relatively short timeframes.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.93)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Mauddud Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Lower Burgan Formation (0.99)
- (16 more...)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
Summary Shales are heterogeneous source rocks that often exhibit complex pore systems. Economical hydrocarbon production from shales necessitates detailed understanding of the complex reservoir characteristics. This paper evaluates several unconventional formations in the Middle East and their dependence on mineralogy, organic matter (OM), clay content and pore type. More than one-thousand data sets from 14 wells and three different formations were analyzed. The analyses started with full-diameter whole cores that were initially evaluated using dual energy X-ray CT scanning to identify potentially high-quality rock intervals with high porosity and high OM. Two-dimensional Scanning Electron Microscopy (2D SEM) and three-dimensional Focused Ion Beam (3D FIB-SEM) analyses were studied to characterize the kerogen content together with (organic and inorganic) porosity, grain size and rock fabric. The mineral framework of the samples was determined from X-ray Fluorescence (XRF), X-ray Diffraction (XRD) and Energy Dispersive Spectral (EDS) analyses. Matrix permeability was directly computed in the 3D FIB-SEM images using the Lattice Boltzmann method. Brittleness Index (BI) was calculated from mineralogy. Trend analyses of the collected data were performed for proper shale evaluation and comparisons. Large property variations were seen in the evaluated formations, and each reservoir showed unique characteristics with overall similar trends. Clay content and organic matter were two main controlling factors that had direct effects on the porosity. Organic matter distribution and pore type were critical parameters in 3D connectivity and determination of permeability. The data provided statistical information and trends about the dependence of shale properties on different factors in the formations under study. These data trends can be linked to the varying depositional environments and diagenetic processes, which were found to have great effects on the rock structure, porosity type, organic matter and petrophysical properties. Such analysis is critical for the understanding of shales in the Middle East, and potential comparisons with shale plays in North America and worldwide.
- North America > United States > Texas (1.00)
- Europe (1.00)
- Asia > Middle East (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline (1.00)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Multi-Scale Rock Analysis for Improved Characterization of Complex Carbonates
Dernaika, Moustafa (Ingrain Inc-Abu Dhabi) | Uddin, Yasir Naseer (Ingrain Inc-Abu Dhabi) | Koronfol, Safouh (Ingrain Inc-Abu Dhabi) | Al Jallad, Osama (Ingrain Inc-Abu Dhabi) | Sinclair, Gary (Ingrain Inc-Abu Dhabi) | Hanamura, Yasuaki (Bunduq Co. Ltd.) | Horaguchi, Keishi (Bunduq Co. Ltd.)
Abstract The evaluation of carbonate reservoirs is a complex task because of the inherent heterogeneities that occur at all length scales. Rock properties may be defined differently at different scales and this introduces a challenge in capturing heterogeneity in a single rock volume. Heterogeneities at smaller length scales must be upscaled into larger scale volumes to better predict reservoir performance. The objective in this study is to define carbonate rock types at multiple scales and then upscale those rock types and associated properties to the whole core level. Representative core plugs were selected in a heterogeneous reservoir interval based on statistical distribution of litho-types in the core. The litho-types were described by porosity and mineralogy variations along the core length using advanced dual energy XCT imaging. Plug-scale rock types were defined on the basis of petrophysical data and geological facies. High-resolution micro to nano XCT images were integrated in the rock typing scheme. Those rock types were upscaled to the whole core level by linking the core litho-types to the plug data. The core litho-types (porosity and mineralogy) gave good representation of the whole core heterogeneity and were reliable for selecting representative samples. This allowed establishing the link between plugs and whole cores and hence upscaling rock type information to the whole core scale. The high-resolution digital images emphasized the different pore geometries in the samples and improved the definition of the rock types. Accurate porosity and permeability logs were derived along the core length and gave very good match with the plug data. Multi-scale porosity-permeability trends were investigated and found to have direct impact on the determination of upscaled permeability log at the whole core level. The paper presents an advanced and quick tool for representative sample selection and statistical core characterization in heterogeneous reservoirs. The identified rock types at multiple scales provided new insights into carbonate heterogeneity and gave upscaling options for rock types and petrophysical data. The upscaled rock types at the whole core level enhance the prediction of dynamic imbibition data along the reservoir column for improved reservoir performance.
- Asia > Middle East > Saudi Arabia (0.28)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)