Design

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Pressure gradient charts compare fluid frictional properties at different rates to ensure proper rheological hierarchy and fluid displacement during pumping.

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Equivalent Circulating Density (ECD) is evaluated at multiple points along the wellbore to ensure fracture gradients are not exceeded and that pressure is maintained across formations with tendency to flow. 

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Dynamic wellbore plots are utilized to identify fluid positions throughout the cement job. Friction and other parameters are measured at discrete points. 

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Section view is utilized to determine fluid velocity and concentration at specific depths to ensure proper drilling fluid removal and cement placement.

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Casing standoff/centralization modeling is utilized to ensure proper centralizer placement based on wellbore conditions.

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

To ensure isolation, Gas Flow Potential (GFP) is modeled at critical locations and severity is reported. 

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

Displacement efficiency is utilized for dynamic analysis of annular fluid concentration, drilling fluid concentration and fluid flow regime at any point and time during the job. 

Image Courtesy of Pegasus Vertex, Inc. / Click image to enlarge

The annular contact time plot ensures that all fluids have sufficient contact time for proper drilling fluid displacement and water-wetting of surfaces.