Fluid Removal TRIZ Cases

A gas lift valve relocates outlet ports to the stationary housing terminal end, isolating movable internal components from reservoir water ingress.

Segmented safety devices prevent premature setting and unintended release in hydraulic packers, resolving shear pin failures from temperature variations.

Selectable inserts adjust the orifice diameter within an inflow control device to balance differential pressures along horizontal boreholes.

A controlled wetting system combines charged polymers and surfactants to lower friction in aqueous treatment fluids.

A one-dimensional fluid flow model integrates governing equations over cross-sections to simulate displacement in well systems.

Asymmetric port geometry in a fluid diode sleeve creates distinct flow resistances that prevent clogging and ensure homogeneous distribution.

A computerized pairing system uses pressure sensors to automatically match manifold valves with fracturing pumps.

Coated persulfate and iron salt gel breakers delay activation until fracture opening, reducing residue while maintaining viscosity stability.

A radial driller multipurpose element integrates a retracting chamber to isolate hydraulic seals from swarf contamination.

A coupled simulation framework integrates basin evolution with geomechanical stress calculations to predict pore pressures in sedimentary basins.

Non-ionic polymer emulsion resists charge screening by multivalent cations to maintain hydrodynamic volume and reduce frictional energy losses.

A one-dimensional flow model represents intersecting well paths using band matrices and intersection tables.

Circular charge holder merges multiple initiators into one unit, reducing assembly complexity while maintaining reliable simultaneous detonation.

Flow constraint material redistributes treating fluid from high permeability fractures to low permeability fractures, increasing hydrocarbon production.

Azo compound initiators stabilize binder gelation time by decoupling polymerization from metal ion catalysis.

Asymmetric rod-shaped ceramic proppants resist settling and collapse in high closure stress environments by mechanically interlocking with each other.

Thickened carbon dioxide streams improve oil recovery by increasing viscosity through polymer additives.

Porous polymer capsules absorb formation water to harden internal cement, reducing fluid viscosity requirements and operational costs.

Scheduling super-heat delivery via a direct steam generator reduces the steam oil ratio by minimizing condensate loss and heat energy wastage.

A multiphase fluid flow model determines slug birth rate using the velocity difference between slug front and tail to initiate slugs.

Reverse emulsions reduce oil volume by 30 to 80 percent while maintaining cavern stability during solution mining.

Solid cyclic dimers and copolymers shorten shear recovery time to 60 seconds or less while reducing required surfactant concentrations.

A composite divert system uses dissolvable particles and proppant to create complex fracture networks in subterranean formations.

Segmented cylindrical cartridge with porous media treats fluids under high internal pressure while preventing particle escape and maintaining flow.

Gas-trapped proppant agglomerates reduce bulk density to prevent premature settling, ensuring complete fracture coverage and conductivity.

Continuous relative permeability model maintains physical consistency during Type II to III phase transitions in surfactant flooding.

Swellable particulates expand against fracture walls to form plugs, allowing proppant settling and creating conductive channels without crushing.

A lightly crosslinked CO2-philic coating increases proppant buoyancy, resolving suspension issues in non-aqueous fracturing fluids.

Segmented proppants reach far-field fractures in tight carbonates, preventing premature closure and reducing fluid loss during stimulation.

Replacing water with oleaginous fluid in Sorel cement prevents formation damage from swelling clays while maintaining effective zonal isolation.

An integrated wellbore injection apparatus uses a sliding sleeve valve to enable radial fluid flow during deployment.

A perforating gun charge tube rotates via a weighted feature to align shaped charges, eliminating disassembly time.

A viscoelastic surfactant treatment fluid forms a solid precipitate barrier to divert displacement flow in subterranean formations.

A liquefied natural gas pump assembly pressurizes and heats LNG before mixing it with base fluid to generate energized fracturing fluid.

Frangible seal melts under thermite reaction to open fluid pathways, eliminating moving part failure in extreme downhole conditions.

Pressure-activated plugs segment the wellbore to prevent proppant settling and ensure complete zone fracturing without flow loss.

Coated proppants solve compatibility issues by using a dissolving coating to release wax inhibitors and pour point depressants directly into the formation.

A processing device generates high-resolution lithology models using dynamic boundary curves calculated from moving windows.

Collapsible fluid containers in a downhole injection tool enable precise treatment fluid delivery using ambient wellbore pressure.

A downhole hydraulic control module operates two actuators using pressure variations in two control lines.

Sequential injection of solvent, hot water, and polymer solution reduces heavy oil viscosity, lowering energy consumption compared to thermal methods.

A fracturing fluid transitions from high to low viscosity to transport proppants effectively.

Mechanical actuators extend swellable packer seals against the wellbore wall, preventing fluid loss during the slow swelling transition period.

Segmenting heterogeneous reservoirs into foam, water, and gas sub-zones improves oil recovery factor accuracy while lowering computational power requirements.

Nano-sized alkaline earth metal oxide additives aggregate formation fines within proppant packs to prevent pore throat blockage.

A plug seat incorporates a flow feature to provide direct fluid access adjacent the tooth.

Integrated workflow predicts frac hit likelihood to minimize parent well production losses from infill fracturing interference.

Adding a radical scavenger delays polymer breakdown by intercepting free radicals, allowing controlled viscosity reduction after proppant deposition.