Depth Dependent Rock Physics Trends for Triassic Reservoirs in the Norwegian Barents Sea

Geologists and engineers need to know more about shales than just pore size and shape. The most important information is how much porosity is connected so that it can provide flow paths for oil and gas, and what is the permeability, or ease with which the hydrocarbons can flow. These needs can be met with a cutting edge technology called Digital Rock Physics (DRP). DRP permits computation of connected porosity, disconnected porosity and directional (X, Y, and Z) permeability from 3D pore space images that are created by the latest generation FIB-SEM apparatus. This article describes how DRP, employing unique and proprietary fluid flow algorithms, has been used by one operator to de-risk exploratory drilling in the Eagle Ford shale of south Texas. Core samples were tested from two wells in the Eagle Ford. Well A is in the early oil window of the Eagle Ford on the northern edge of the play. Well B, near Hawkville Field, is in the late oil window. DRP was shown to be an effective and expeditious method to characterize this very “tight” (low permeability) formation and provided data that might otherwise have been difficult or impossible to obtain from conventional core laboratory methods.