Representation of multiscale heterogeneity via multiscale pore networks

Developing a better understanding of single-/multi-phase flow through reservoir rocks largely relies on characterizing and modelling the pore system. For simple homogeneous rock materials, a complete description of the real pore structure can be obtained from the pore network extracted from a rock image at a single resolution, and then an accurate prediction of fluid flow properties can be achieved by using network model. However, for complex rocks (e.g., carbonates, heterogeneous sandstones, deformed rocks), a comprehensive description of the real pore structure may involve several decades of length-scales (e.g., from sub-micron to cm), which cannot be captured by a single-resolution image due to the restriction of image size and resolution. Hence, the reconstruction of a single 3D multiple-scale model of a porous medium is an important step in quantitatively characterising such heterogeneous rocks and predicting their multi-phase flow properties.

In this paper, we present a novel methodology for the numerical construction of the multi-scale pore structure of a complex rock from a number of CT images/models of a carbonate sample at several length scales. The success of this reconstruction relies heavily on image segmentation, pore network extraction and stochastic network generation, which are provided by our existing software system, referred to as Pore Analysis Tools (PAT). Specifically, the statistical description of pore-networks of 3D rock images at multiple resolutions makes it possible for us to: (a) construct an arbitrary sized network which is equivalent in a specified domain, and (b) integrate multiple networks of different sizes into a single network incorporating all scales. Using multi-scale networks of carbonate rocks generated in this manner, two-phase network modeling results are presented to show how the resulting flow properties are dependent on inclusion of information from multiple scales. These outcomes reinforce the importance of capturing both geometry and topology in the hierarchical pore structure for such complex pore systems. The example presented reveals that isolated large-scale (e.g. macro-) pores are mainly connected by small-scale (e.g. micro-) pores, which in turn determines the combined effective petrophysical properties (capillary pressure, absolute and relative permeability). It is also demonstrated that multi(three)-scale networks reveal the effects of the interacting multi-scale pore systems (e.g. micro-pores, macro-pores and vugs) on bulk flow properties in terms of two-phase flow properties.