Progressive Cavity Pump Systems

The core pumping element, comprising a chrome- or coating-hardened single-helix steel rotor and a bonded elastomer double-helix stator. Sizing is specified by displacement (rate per 100 rpm) and pressure capability (number of stages/lobes).

Wellhead drive assemblies that transmit torque from a surface electric or hydraulic motor through a rod string to the downhole pump, incorporating a thrust bearing, stuffing box, and braking system to control rod-string back-spin.

Rodless configurations in which a downhole electric motor and gear reducer or speed-reduced drive turn the rotor directly, eliminating rod-string wear and suited to deviated and horizontal wells.

The rod string and accessories that link the drivehead to the rotor, including rod centralizers that reduce tubing wear and rod-on-tubing contact in deviated wells, and shear or torque couplings used in the string.

Sacrificial torque-limiting couplings installed in the drive train that shear at a set torque to protect the rotor, rod string, and drivehead from damage during stalls or solids lock-up.

Downhole landing and spacing components, including the tag bar that sets rotor depth within the stator and tubing anchors or no-turn tools that resist tubing rotation and movement under torque.

Pump variants with elastomer compounds (e.g., nitrile, hydrogenated nitrile, or fluoroelastomer grades) selected for resistance to aromatics, H2S, and elevated bottomhole temperatures common in heavy and thermal-recovery wells.

Motor controls, variable-speed drives, and back-spin/brake control packages that regulate pump rpm, manage rod-string energy on shutdown, and protect against dry-running and over-torque.