Completion Fluids

Single- or mixed-salt brines based on monovalent cations such as sodium chloride, potassium chloride, sodium bromide, and potassium bromide. They provide densities up to roughly 12.5 lb/gal and are valued for low formation damage and compatibility with clay-sensitive zones.

Higher-density brines based on divalent cations, including calcium chloride, calcium bromide, and zinc bromide blends. They reach densities up to about 19.2 lb/gal for high-pressure wells but require attention to crystallization temperature and corrosion control.

Fluids left in the annulus between tubing and casing above a production packer for the life of the well. They are formulated for long-term stability, low corrosivity, and the right density to balance casing and tubing loads.

Specialized non-damaging fluids used to drill through the pay zone, typically with sized bridging solids (such as sized calcium carbonate) that form a thin, removable filter cake to protect formation permeability.

Breaker systems and cleanup fluids that dissolve or degrade the filter cake deposited by drill-in fluids, commonly using acids, enzymes, oxidizers, or chelants to restore near-wellbore permeability before production.

Surfactant, solvent, and viscosified pill systems used to displace drilling mud and remove residual solids, films, and oil from casing and tubing prior to completion.

Performance chemicals blended into brines, including corrosion inhibitors, oxygen scavengers, biocides, viscosifiers, fluid-loss control agents, and pH buffers tailored to the base brine and downhole conditions.

Weighted brines or fluids circulated to suspend or stop well flow during workover and intervention, providing the hydrostatic head needed to control formation pressure safely.