Detailed core sedimentological description (scale 1:50) is done digitally using the WellCAD software. The core description is supported by an integrated presentation in WellCAD format with other available data, such as wireline logs, routine core analyses, petrographic and geochemical information and borehole image logs. Logged sedimentological parameters in core are including, but not restricted to: lithology, bed contacts, texture, sedimentary structures, physical structures, body fossils and ichnofossils, color, diagenetic features, visual porosity, oil show and fractures. Each bed or bed set will be assigned a lithofacies code and recurrent lithofacies types will be grouped into lithofacies associations. The latter will be interpreted in terms of depositional environment based on the stacking patterns and supporting circumstantial geological evidence (i.e. surface discontinuities, changes in fossil assemblage, rock microfacies, etc.). On request, images of the slabbed core will be taken, utilizing a digital, high resolution camera equipped with prime lenses and light sources. The core photography set up is equipped for both white light and UV light photography.

One of the key challenges in reservoir characterization is the understanding of the geometrics and behaviour of natural fractures in a reservoir. Fractures occur in most reservoirs and are, at the core scale, generally easy to identify. However, to get a full understanding of the fractures and their properties in relation with the reservoir can be very complex. A detailed fracture study improves the understanding of the reservoir and allows for a more realistic reservoir model. PanTerra is able to perform a full-scale, integrated and interdisciplinary fracture study involving both core analysis and borehole imaging, which allows data extrapolation at well scale, and eventually at reservoir scale. Fracture density and orientation measurements are combined and artificial vs. natural fractures are discerned. Integrating the results, leads in a more complete understanding of the tectonic regime and eventually the reservoir properties themselves.

A. Rock depositional micro-facies and pore network - At PanTerra the thin sections are described quantitatively by point counting, as well as qualitatively in terms of dominant rock fabric, microfacies, mineralogy, pore types, biotic components or diagenetic overprints. Grain size and sorting are also measured from thin sections either exactly by point counting or approximately by comparator method. An interpretation of the paragenetic sequence can be supplied, as well as photomicrographs and comprehensive petrographic descriptions. Whenever possible, a rapid petrographic screening of existing thin sections should be done as preparation for core description, so that important sedimentologic and diagenetic features can be properly recognised and recorded during core logging. B. Diagenesis study for Reservoir Quality Assessment - For a better understanding of pore space cementation, mineralogy and the variability of authigenic mineral phases PanTerra offers a wide range of advanced petrographic methods, which are available in-house or using our certificated third parties. PanTerra can provide high standard and cost-efficient diagenetic studies using the following analytical methods: X-Ray Diffraction, SEM-EDAX, Fluid Inclusions thermometry, Cathodoluminescence, UV Fluorescence , bulk Chemistry, Carbon, Oxygen and Strontium stable isotopes.

Porosity prediction is addressed by identification of the main porosity-controlling processes (depositional + diagenetic) and evaluating how these processes vary on the scale of interest (well, reservoir, basin). PanTerra can evaluate and integrate the available empirical data and review RCA, SCAL methodologies, and legacy geological studies that might serve as analogues. Permeability is best interpreted by first considering its relationship to total porosity. Permeability-for-given-porosity can be evaluated by examining dominant pore types and how these have been controlled by geological setting (depositional texture and sequence stratigraphy) and diagenesis. These data can be combined with in-house measurements of capillary entry-pressures by high-pressure mercury (Hg) injection. Integrating cap curve analysis with petrographic and petrophysical data is critical for accurate rock typing, which is an important input for reservoir modelling.