Permeability Upscaling for Carbonates from the Pore-Scale Using Multi-Scale Xray-CT Images
- Ahmad Dehghan Khalili (U Of New South Wales) | Christoph Hermann Arns (University of New South Wales) | Jiyoun Arns | Furqan Hussain (U. of New South Wales) | Yildiray Cinar (U. of New South Wales) | Wolf Val Pinczewski (U. of New South Wales) | Shane Latham (Australian National University) | James Joseph Funk (Saudi Aramco)
- Document ID
- Society of Petroleum Engineers
- SPE/EAGE European Unconventional Resources Conference and Exhibition, 20-22 March, Vienna, Austria
- Publication Date
- Document Type
- Conference Paper
- 2012. Society of Petroleum Engineers
- 4.3.4 Scale, 5.5 Reservoir Simulation, 5.8.7 Carbonate Reservoir, 5.3.1 Flow in Porous Media, 5.1.5 Geologic Modeling, 4.1.5 Processing Equipment, 5.6.1 Open hole/cased hole log analysis, 5.6.2 Core Analysis, 5.1 Reservoir Characterisation, 5.5.3 Scaling Methods, 5.5.2 Core Analysis, 1.6.9 Coring, Fishing, 4.1.2 Separation and Treating, 5.8.5 Oil Sand, Oil Shale, Bitumen
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High-resolution Xray-CT images are increasingly used to numerically derive petrophysical properties of interest at the pore scale, in particular effective permeability. Current micro Xray-CT facilities typically offer a resolution of a few microns per voxel resulting in a field of view of about 5 mm3 for a 20482 CCD. At this scale the resolution is normally sufficient to resolve pore space connectivity and transport properties. For samples exhibiting heterogeneity above the field of view of such a single high resolution tomogram with resolved pore space, a second low resolution tomogram can provide a larger scale porosity
map. The problem then reduces to rock-typing the low resolution Xray-CT image, deriving viable porosity-permeability transforms from the high resolution Xray-CT image(s) for all rock types present, and upscaling of the permeability field to derive a plug-scale permeability.
In this study we characterize spatially heterogeneity using overlapping registered Xray-CT images derived at different resolutions spanning orders of magnitude in length scales. A 38mm diameter carbonate core is studied in detail and imaged at low resolution - and at high resolution by taking four 5mm diameter subsets, one of which is imaged using full length helical scanning. Fine-scale permeability transforms are derived using direct porosity-permeability relationships, random sampling of the porosity-permeability scatter-plot as function of porosity, and structural correlations combined with stochastic simulation. A range of these methods are applied at the coarse scale. We compare various upscaling methods including renormalization theory with direct solutions using a Laplace solver and report error bounds.
We find that for the heterogeneous samples permeability typically increases with scale. Conventional methods using basic averaging techniques fail to provide truthful vertical permeability due to large permeability contrasts. The most accurate upscaling technique is employing Darcy's law. A key part of the study is the establishment of porosity transforms between highresolution and low-resolution images to arrive at a calibrated porosity map to constraint permeability estimates for the whole core.
|File Size||4 MB||Number of Pages||17|