Fluid Removal TRIZ Cases

An amorphous polymeric web captures proppant to prevent flowback, then degrades via hydrolysis to maintain fracture permeability.

A tubular with pressure-responsive valves directs fluid flow between isolated wellbore fractures based on internal pressure differentials.

An exfoliating agent comprising glycerin carbonate and alkoxylated alcohols increases the viscosity of non-aqueous base liquids.

A wellbore packer setting mechanism transfers axial force around the seal member to engage slips before compressing the elastomer.

High-energy spark initiator vaporizes borehole water into live steam, replacing costly mechanical pumps to lower operating expenses and improve safety.

A valve system restricts base pipe flow via pressure signals to resolve carrier fluid return restrictions in well completions.

In-situ reinforcing objects form around wellbores to prevent land subsidence caused by hydrocarbon extraction compaction.

Approximate covariance matrix enables Karhunen-Loève expansion, resolving computational infeasibility of large-scale reservoir models.

Movable screen members dynamically shift positions to inject proppants while preventing particulate backflow into the borehole.

Selective port registration via a sliding mandrel manages cement pressure in porous formations, preventing formation breakdown during deep well cementing.

Axial pistons secure wellhead seals via hydraulic pressure, reducing component count and installation time.

A gas accumulator section stores gas to displace liquids from the production conduit into the annular space.

A cylindrical repair device with mechanical anchors and packers restores mechanical integrity in small-diameter production tubing.

Rupture disk on plug body creates inlet via hydraulic pressure, simplifying cement flushing in wellbores.

A liquid dispersion polymer composition mixes with seawater to form an injection fluid with improved viscosity and stability.

Crosslinked polymeric coatings on proppant surfaces increase particle aggregation to form stable clusters.

A moveable cover restricts slip movement until an actuator releases it for radial expansion.

An intermediary shock mitigator absorbs bidirectional energy to protect sensitive electronics from gun shock damage during hydrocarbon well operations.

Capillary number dependent correlations adjust gas relative permeability to resolve static curve inaccuracies in heavy oil solution gas drive simulation.

Dissolvable water-soluble glass plugs eliminate debris and complex retrieval operations by dissolving completely upon contact with wellbore fluids.

Direct plasma heating eliminates silica contamination and boosts heat transfer efficiency in steam-assisted gravity drainage.

An expandable non-frangible slip ring displaces gripping members radially outward to secure downhole tools.

Multi-scale zirconium gel particles aggregate in the stratum to control water flow, avoiding polymer viscosity loss from mechanical shearing.

Segmented fluid passages with differential resistance route steam to condense via Venturi effect, preventing heat waste and erosion damage.

Segmented hollow hydrogel capsules modulate chemical concentration and reactivity during transport, preventing premature borehole exposure.

Insulated containers withdraw liquid CO2 from high-pressure pipelines to prevent equipment damage from low temperatures and stop atmospheric venting.

Radio frequency electromagnetic radiation accelerates hydratable polymer hydration, replacing large mechanical units and reducing operational costs.

Acoustic and pressure sensors monitor sand accumulation to trigger automated dumping, preventing gas release into the disposal line.

Simultaneously introduces curable resin and curing agent emulsions via micelle sequestration, eliminating sequential fluid steps that increase treatment time.

Beam springs maintain radial grip on tubulars after morphing, preventing loosening and preserving axial load capacity.

Acidic nanosilica dispersion and polyethylene polyamine form a gelled solid to block fluid loss paths in wellbores.

Vaporizing expandable fluid fragments coal to enlarge cavities, avoiding cleat damage from hydraulic fracturing.

Viscoelastic fracturing fluids use critical solution temperature surfactants to deliver high viscosity for proppant transport.

Strong acid injection dissolves downhole ceramic disks, eliminating mechanical milling delays and tool lock-up risks during well stimulation.

Amino acid additives buffer caustic compositions to stabilize pH levels, lowering freeze points while reducing dermal damage risks.

An eccentric orienting device misaligns the charge tube axis so gravity rotates it, directing shaped charges in non-vertical wellbores.

Periodic acoustic pulses replace static pressure to distribute energy uniformly, creating isotropic fracture networks.

Electrolytic hydrogel resists thermal degradation and saline sensitivity by using specific functional groups to stabilize viscosity at elevated temperatures.

Segmented rotor chambers transfer pressure from clean to dirty fluids, reducing abrasive wear and extending pump functional life.

A method calculates surfactant concentration using only water and surfactant volumes to simulate microemulsion systems accurately.

Two-stage optimization adjusts field-level parameters and thief-zone distributions to enhance history matching accuracy.

A polymer-derived ceramic precursor converts to a porous network at low temperatures, enabling filler infiltration.

Segmented proppant sizes navigate fracture networks to prop open small far field cracks that conventional particles cannot reach.

Helical passages in the inflow control device impose a pressure drop to eliminate cross-flow interference and optimize hydrocarbon production.

An isolation mandrel with a radially enlarged transition chamber guides an isolation device to selectively block or permit fluid flow within a tubing string.

AC-PAD modified water-based muds inhibit shale expansion, reducing borehole instability and drilling costs.

Washout assembly removes excess gravel to enable precise cement packer placement above the sealed zone.

Exterior bypass tubes span threaded joints via a sealed internal mandrel to unify fluid connections across screen sections.

A downhole fluid separator divides formation fluids into production and nonproduction streams at the well junction.