Fluid Removal TRIZ Cases

On-site welding eliminates material waste from fixed liner lengths while ensuring a reliable watertight seal against moisture ingress.

A lock mandrel uses a spring-loaded locking collar to maintain downhole pump position against pressure differentials.

Dynamic well site planning adjusts reservoir targets and trajectories in real time, resolving the trade-off between manual control and planning speed.

Mineralogical logging identifies productive zones and reduces clay hazards, resolving low hydrocarbon production from random cluster selection.

A downhole impact generator delivers controlled jarring force to dislodge stuck well tools using a motor-driven moveable shaft.

Mechanical vibration breaks cohesive bonds in wet sand, enabling reliable flow through a tipping mechanism without drying.

A downhole flow control device uses a moveable regulator member to autonomously adjust fluid restrictions based on flow direction.

A thermochemical treatment fluid generates nitrogen gas and heat to form a multi-phase foam that displaces condensate banking in wellbores.

Segmented retaining rings prevent cap ejection from residual pressure while venting ports enable gradual pressure release during removal.

Recovers surfactants and polymers from produced fluids to reduce chemical consumption and operational costs.

Segmented deployment uses a spoolable conveyance with a downhole barrier valve to install pumps without lifting the wellhead.

A well treatment fluid combining sepiolite clay with acryloylmorpholine or polyvinylpyrrolidone polymers to maintain rheological properties.

Segmented pleats unfold radially to retain high differential pressure, bypassing fluid flow and eliminating petal overlap reliability issues.

Ball dropper assembly automates frac ball placement, eliminating manual worker exposure to hazardous wellbore zones.

A sensor assembly uses SAW and chemiresistor arrays to detect mercury analytes in fluids.

Passive downhole fractionation uses pressure differentials to separate fluids without power, eliminating mechanical pump complexity.

Modular asset control units bundle hydraulic, lubricant, and sensor lines into standardized umbilicals to reduce hose connection complexity during well setup.

Heater strings with electric resistive heating elements inject gaseous solvents to mobilize hydrocarbons in subsurface formations.

Dynamic valve adjustment maintains safe flow velocities, preventing wellbore collapse while maximizing production efficiency.

Replacing mechanical linkages with hydraulic fluid coupling reduces component wear and maintenance costs in high pressure fracturing pumps.

Hydrophobic nanoparticles stabilize and break down micellar structures via temperature changes, resolving delayed well cleanup in hydraulic fracturing.

Breakable threads on a frac plug mandrel hold slips in place during pumping, preventing premature setting caused by fluid pressure changes.

Inducing tube waves in wellbore fluid enables non-invasive sand-pack characterization using surface pressure measurements.

Biodegradable chemical activators gel aqueous silica sol in situ, reducing permeability and eliminating polymer degradation risks at high temperatures.

Rotating nozzles cut notches past hoop stresses to prevent longitudinal fractures and screen-outs.

Uniform inner bore casing design eliminates complex electronics and large base structures while enabling independent zone control.

A float collar tool creates a buoyancy chamber using light fluid to reduce casing string weight.

A perforating insert seals a casing port until threshold pressure ejects the core as a projectile to enhance fracturing.

Perforated outer shroud limits screen expansion to prevent over-expansion and maintain structural integrity during deployment.

Alternating acid and proppant injections blocks existing fractures to initiate new ones, solving the lack of zonal isolation in highly deviated wells.

Formamide and organic acids reduce the true crystallization temperature of calcium bromide brines, preventing precipitation in cold weather.

Segmenting proppant into pillars via periodic fluid adjustments resists formation closure stresses and maintains fracture conductivity.

Stable emulsions with colloidal silicon dioxide nanoparticles selectively block water-saturated intervals to enhance oil production.

Thermally stable synthetic hectorite and smectite clays swell to block flow paths, preventing fluid communication at temperatures above 200°F.

A hydrocarboxylic acid derivative delays cement curing to extend pumpable slurry duration at elevated downhole temperatures.

A drain line extracts trapped fluid columns between closed inline valves, resolving pressure differentials that cause leakage and erosion.

Specific surfactant ratios enable spontaneous phase inversion, maintaining polymer reliability in high salinity brines.

Segmented skid assemblies reduce conduit lengths and deployment costs by assigning dedicated units to individual wellheads.

A formation saver sub uses a piston and spring mechanism to manage fluid pressure.

Oil-in-water nanoemulsions mobilize heavy oil in high salinity reservoirs by lowering injection energy requirements.

A motorized plunger catcher actuator extends and retracts a rod to capture and release plungers in wellhead lubricators.

A pumping device evacuates hydraulic fluid from a first chamber to reestablish low pressure in a subsea recipient.

Segmented tubular portions expand compliantly into worn casings to secure coupling while minimizing hydraulic lock risks during sealing operations.

Solid retarded acid particles suspended in non-reactive liquid resolve high friction and shaft corrosion issues while enabling long fracture creation.

In situ acid generation etches microfractures while curable resin prevents particulate migration and channel plugging.

Self-degrading particulates temporarily block existing fractures to prevent fluid loss during refracturing operations.

Extracting the valve from the tubing string into the casing wall resolves repair complexity and allows retrofitting existing wells without pulling tubing.