FracSCAN technology is based on a pressure-based fracture map computed using our patented data acquisition and processing. The data source is a surface pressure gauge on a monitor well—established through isolation from prior stages—that records the poroelastic pressure response from a nearby treatment well during hydraulic fracturing. As the treatment well is fracked, our geoscientists and completion engineers identify and quantify the poroelastic signals from the monitor well’s measured pressure response.
We use the poroelastic signals to compute a simple, accurate, affordable pressure-based fracture map by matching the observed responses in the monitor well to a digital twin. The fracture map includes fracture half-length, height, asymmetry, and azimuth and how fast these dimensions grew.
The pressure-based fracture map data support four other services that let you:
With this information, you can decide if or when you need to change the stimulation treatment, including proppant size, to match a development’s varying geology.
Is fracking with a mixed proppant size or single proppant size better?
Does adding 100-mesh proppant affect fracture geometry?
An Eagle Ford operator asked us to analyze the effect of several completion design changes across three pads in south Texas. Several completion parameters—fluid type, proppant loading, number of clusters, and stage length—were varied as fracking proceeded on the pads. Because the goal was to establish the optimal parameters for each component for future completion designs, the operator needed to understand the fracture geometry and the geometry differences as a parameter was changed.
Across the three pads, adding 100-mesh proppant to the proppant design enabled 14% larger fractures compared with the stages that had only 30/50-mesh proppant. With FracSCAN technology, the operator made informed, better completion decisions about the right fluid design.