Energy, oil and gas extraction, technological processes
DigitalROCK offers the first cloud solution for accurate and reliable forecasting of multiphase reservoir flow properties. It utilizes patented digital physical modeling technology to reduce the time and cost of core sample analysis. The increase in the volume and speed of research provides more quality data for making key decisions, especially for oil and gas companies evaluating enhanced oil recovery projects.
DigitalROCK is the first accurate and reliable numerical solution for modeling relative permeability of reservoirs, which includes enhanced oil recovery (IOR/EOR) simulation. DigitalROCK is a virtual specialized laboratory that allows you to work on rock sample classification, perform pore space analysis, and conduct research. With the multiphase fluid flow simulator, this solution can accurately model flow through a porous medium representing a hydrocarbon reservoir, directly at the “micro-level” – with real pore geometry.
The DigitalROCK solution was developed in a long-term partnership with BP and is based on 25 years of experience from the SIMULIA team in Lattice Boltzmann (LBM) development. Using advanced numerical modeling technologies for multiphase flows based on LBM, we have created a reliable solution for predicting the relative permeability of reservoirs, which industry leaders refer to as the “Holy Grail.” With DigitalROCK, you can easily obtain data on pore space, mercury capillary pressure, absolute permeability (k 0), capillary pressure curves, and most importantly, the accurate relative permeability curve (kr). The virtual laboratory allows for fundamental analysis in just days, rather than months (as in a traditional laboratory).
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