Fluid Removal TRIZ Cases

The system generates and simulates well-action scenarios to improve reservoir modeling accuracy and reduce assessment time.

Brine-rich polyglycerol-10 ester reverses tight-rock wettability, improving oil recovery with lower energy use.

This case uses a retrievable cyclonic desander and bumper assembly to limit plunger wear and maintenance downtime.

A low-power electrical line drives a downhole hydraulic pump, avoiding surface control lines exposed to high pressure and temperature.

A converging-diverging nozzle with spiraling vanes converts gas energy into directed flow for more effective production-fluid lifting.

This case integrates faults, lithofacies, and zigzag connectivity to model vertical and lateral migration channels.

A dual-tank loop prevents recirculation bias while inline injection and controlled shear improve friction reducer evaluation.

This case pairs a polyolefin matrix with petroleum coke to improve fracture transport, retention, and hydraulic conductivity.

Density-driven shiftable elements align or misalign flow openings to admit desired fluids and restrict gas or water in wells.

After thermal recovery, an end-of-life well uses latent heat to capture hydrocarbons left in stranded reservoir zones.

This case shows how electrical actuators and a ball screw vary gas lift orifice openings for real-time injection control.

A clip-on resistorized detonator uses a biased arm to shunt current, simplifying safe transport, assembly, and reliable initiation.

A pressure-deployed flexible liner anchors to the wellbore wall, then cures in place to seal irregular voids and preserve integrity.

This case uses bioderived graphene to extend cement slurry placement time without dispersion while supporting hardened strength.

This case removes casing locally and cuts triangular notches into rock to widen the wellbore and reduce tortuous flow.

This case uses controlled pressure pulses to fracture and dilate reservoir rock, improving water injectivity without acidification.

Conductive SAGD heat lowers viscosity while microbial gas pressure mobilizes IHS oil, reducing steam use and emissions.

Separate cannister-to-sting paths provide controlled treatment-fluid delivery, reducing uneven filling and leak paths around the tubular.

Chemical vapor deposition coats internal and external sand screen surfaces to reduce erosion and extend assembly service life.

Gas separators, dual tubing strings, and gate mechanisms divide phases, supporting ESP reliability without annulus production.

A solid cone and collapsible cone, secured by a shear pin, support reliable HPHT liner hanger expansion with lower pullout force.

A detonator housing integrates a cord receptacle and stop to control overlap depth, reducing over-insertion during assembly.

Hydraulic fracturing and acidic proppant dissolution create sealed shale fractures that contain CO2 and reduce leakage risk.

A nested-tube helical auger separates gas from liquid before the pump, improving volumetric efficiency and equipment life.

A side-pocket mandril integrates an electric actuator and fail-safe spring for remote gas flow adjustment without well intervention.

In-situ liquid proppant pillars maintain fracture conductivity while reducing settling.

Aqueous fluids with polymer friction reducers cut lateral wellbore pressure drop, improving distribution toward the wellbore toe.

Produced fluid carries treatment material through a passive elution device into the wellbore for continuous corrosion inhibition.

Pressure-signature detection and electronic actuation control the running-tool valve for reliable liner hanger setting during circulation.

Manual valve selection slows gas lift planning; a digital twin analyzes well data to guide continuous or intermittent designs.