Reservoir understanding leads to operational success
Optimal slurry and fluid designs for harsh reservoir conditions
High-temperature wells are traditionally defined as having a bottomhole temperature at or above 300°F (150°C). While there are no differences in the construction, stimulation and production of these wells, the harsh reservoir conditions can limit the use of certain technologies.
For primary cementing operations, excessive temperatures can change material rheological properties, causing cement to cure more slowly, reducing thickening time and taking longer to set. Also, high temperatures are more common in deeper wells, which translates to a narrower annulus and more corrosive conditions.
For fracture stimulation operations, high temperature wells create challenges such as excessive shear, rapid loss of viscosity, narrow fracture widths, fluid loss and poor proppant transport.
Understanding bottomhole and differential temperatures enables BJ Services to optimize slurry and fluid design and select solutions based on the reservoir conditions. We offer an array of slurries, fracturing fluids and additives that deliver an effective cement bond, zonal isolation and fracture stimulation in high-temperature operations.