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Multiphase flow predictions carbonates Relative permeability
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Formation properties tight gas Optimize stimulation
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Understand heterogeneities shale gas Maximize recovery
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Fractures, vugs, matrix mixed wet carbonates Oil recovery factors
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Residual oil saturation transition zones Oil relative permeability
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Fractional flow estimation layered reservoirs Relative permeability curves
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Capillary pressure complex clastics Primary and secondary recovery factors
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Effective and relative permeability CBM Reserves and deliverability
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Working to improve recovery factors worldwide

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iRock Technologies provides innovative digital core analysis software and services to improve recovery in conventional and unconventional oil and gas reservoirs.

We are transforming how 3D rock images are analyzed to predict petrophysical parameters and fluid flow properties. Using industry-standard analytical tools and our proprietary RockDNA* pore network modeling technology, we provide reservoir answers to geoscientists and engineers significantly faster than any other provider. Our 3D image analysis and computation methodologies have been validated in many refereed scientific journals, and we are partnering with key oil and gas companies to champion the application of digital core analysis techniques to improve reservoir characterization.

Let us know how we can help you discover the benefits of pore network modeling technology. We don't just look at the grains, we predict the primary drainage capillary pressure and the relative permeabilities of oil, gas and water.

Multiphase flow predictions from carbonate images

A methodology to extract networks from pore space images had been developed and tested to make predictions of multiphase transport properties for subsurface carbonate samples. The extraction of the network model is based on the computation of the location and sizes of pores and throats to create a topological representation of the void space of 3-D rock images. The analysis leads to predictions of relative permeabilities for primary drainage, waterflooding, and secondary drainage that agree well with laboratory measured values. DOWNLOAD TECHNICAL PAPER

Pore-scale modeling: Effects of wettability on waterflood oil recovery

The effects of wettability on waterflood oil recovery can be analyzed using a capillary-controlled pore-scale network model. The model has been validated against experimental data in the literature and on mixed-wet Berea sandstone and then applied to study multiphase flow through four networks extracted from different types of rock: a sand pack, a poorly consolidated sandstone from the Middle East, a granular carbonate and Berea sandstone. Hypothetical optimal recovery results are explained in terms of pore-scale displacement mechanisms and fluid configurations. DOWNLOAD TECHNICAL PAPER

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