Fluid Removal TRIZ Cases

Evaluate distance, pressure, depth, and injection factors to recommend injector shutdowns while protecting drilling safety and production.

Concentric rings, helical grooves, and a canted-coil clutch control sealing and flow during plunger descent and ascent.

A rock-adsorbed modified resin treatment keeps paraffins dispersed, limiting deposition and reducing repeated well maintenance.

This case uses branched poly(hydroxyacid) polymers to speed water degradation and reduce costly downhole tool removal.

Covalently bonded amine shells help nanoparticles remain stable in hot, high-salinity brine, supporting hydrocarbon recovery.

A scheduled control subsystem sequences fluid valves in parallel, helping well teams avoid bottlenecks and corrective actions.

Upward ports separate downhole gas from liquids, reducing turbulence and protecting pump efficiency.

A gas separator and dual tubing strings route gas and liquid separately, supporting multiphase ESP production while limiting corrosion.

A plug, replacement gate block, and sealed cable hanger enable ESP deployment while preserving well pressure and productivity.

Automated status monitoring links treatment pumping, pump-down conveyance, and valves to increase active well-service hours.

Pressure-driven pistons extract well fluids in deviated and horizontal wells while flushing gas and limiting rod-related wear.

Staged heating and tannin-amine bonding address inconsistent manufacturing and fluid loss in drilling fluids.

This hydraulic fracturing case uses cumulative leak-off volume and stiffness changes to resolve ambiguous closure pressure readings.

A particulate buffer preserves plug integrity and zonal isolation through multistage fracturing before eventual dissolution.

A radial electrical switch reduces initiator axial length, allowing more guns and production zones in a perforating tool string.

This case uses in-line mixing and surfactants to invert liquid polymers rapidly, improving flow through porous formations during EOR.

Dynamic permeability and special gridding capture fracture overlap, helping optimize fracture locations and production rates.

Hydraulic fracturing with CO2-enriched weak-acid fluid increases reactive rock permeability without insoluble phase blockage.

Urea-derived compounds, quaternary ammonium compounds, and surfactants moderate acid reactivity for deeper, less-branched wormholes.

Separate initiator components simplify regulated transport and enable on-site detonation.

Two parallel pumps reach 4,200 gallons per minute, while a baffle smooths convergence for balanced, transportable operation.

Encapsulated complexing or reducing agents release at targeted times to form soluble iron products and limit plugging and erosion.

This case uses oxalatization to convert metal oxides into oxalates, enabling rapid and scalable carbon storage in rock.

A spring-biased mechanism switches flow paths to flush solids into the annulus, maintaining filtration and protecting downstream tools.

A capillary tube and tank track liquid-level changes to replace costly high-pressure tests for surfactant screening.

A movable detonator holder connects the detonator to the ballistic train during assembly, reducing tool length and assembly errors.

This case routes liquids from fractured horizontal wells to a pumped vertical well, reducing backpressure and improving recovery.

Surfactants help invert liquid polymer compositions in saline aqueous media, improving injectivity without plugging porous formations.

A Polyhalite, NaCl, and SiO2 solution uses beneficial ions to promote imbibition and improve oil recovery in carbonate reservoirs.

This case uses friction-reducing subs to centralize plugs and protect sealing elements while isolating tightly spaced zones.

Oil-wet coke fines help prop primary and secondary fractures, reduce fluid loss, and expand stimulated reservoir volume.

Exothermic salt reactions heat starch fluids underground, increasing viscosity to block high-permeability zones and divert recovery fluids.

Using lower-density coke proppant particles helps refracturing fluids reach under-stimulated areas while sustaining fracture conductivity.

A staged proppant-fiber schedule forms low-permeability plugs that contain fracture height and length at far-field tips.

This case uses segmented fractures, sparse mirror grids, and transmissibility calculations for efficient 3D reservoir simulation.

A gas-generating resin treatment consolidates weak sand formations, limiting sand mobilization while retaining productive permeability.

Sequential fluids combine coke and non-coke proppants to extend transport, support conductive fractures, and reduce fluid complexity.

This case combines 10–67 vol% coke with non-coke proppants to improve transport, limit settlement, and maintain fracture conductivity.

Conical or tapered liners redirect explosive force, creating elongated casing perforations without major gun redesign.

This case uses oil-wet petroleum coke proppants to ease oil entry at fracture interfaces while repelling water.

Coke proppant particles reduce settling and erosion, supporting uniform distribution and hydraulic conductivity across long fracture stages.

This hydraulic fracturing approach uses coke particles and low-base-viscosity fluids to support fracture conductivity and recovery.

A low-pressure centerbore enables high-pressure exchange with standard seals and motors.

Traditional welded manifolds require many parts and long fabrication; HIP integrates headers, valves, and piping compactly.

Integrated contacts in charge segments reduce wire damage and firing failures.

Separate annular gas and liquid paths ease downhole gas buildup, supporting pump operation and higher well production.

This case uses multiple moving windows and classifiers to objectively characterize subsurface features in continuous data.

Radially offset shaped charges create more casing flow area by avoiding adjacent-charge contact and reducing shock interference.

Calcium-deficient calcium silicate reacts with CO2 to create low-density foamed cement that fills annuli and sequesters carbon.

This case addresses declining well utilization after depletion by sequencing CO₂-enhanced recovery with underground hydrogen storage.