Fluid Removal TRIZ Cases

A layered linear inversion technique locates microseismic events using discrete velocity layers and arrival time mismatches.

A subsea pressure compensation piston uses a differential area design to balance seawater and hydraulic fluid pressures for reliable depth operation.

A Cho-Venturi tube combines primary and recirculation flows to generate pressure for water expulsion.

Acid-functional polyvinyl alcohol blends degrade via hydrolysis to maintain formation permeability after diverting servicing fluids.

A spatially varying impedance sleeve models downhole fluid pressure distribution, resolving suboptimal perforation design caused by inaccurate simulation.

Flanged inserts protect crossover sub housing from erosion, preventing bypass streams that compromise structural integrity.

Segmented laterals and dimensionality changes reduce water consumption while accelerating oil recovery.

Sacrificial blast plates shield reusable bulkheads from detonation temperatures, eliminating extensive cleaning and reworking after each use.

Surrogate models replace time-consuming numerical simulations with probabilistic estimates, optimizing well placement and fluid flow management.

Replacing failing progressive cavity pumps, pressurized methane generates foam that lifts water and solids from coal seam wells.

Alkyl ether phosphates trigger gel breakdown via formation conditions, eliminating the need for external flush fluids to improve oil recovery.

Strategic flow restriction elements on the base pipe distribute fluid evenly, preventing erosion in poorly packed gravel regions.

Hydrostatic pressure shifts the actuator to disarm the carrier, resolving the reliability versus complexity trade-off for liner separation.

Barrier device actuates to restrict flow through the screen assembly, resolving pressure loss during gravel packing operations.

Dynamic viscosity changes allow the sealant to flow easily during introduction while preventing slumping and dilution in horizontal wellbores.

Porous shape memory foam minimizes sand entry and erosion damage, maintaining permeability in non-uniform boreholes.

A computer method quantifies stimulated reservoir volume uncertainty using probabilistic microseismic event distributions.

A mechanical cutter tool rotates within a tubular to cut through material without open flame.

Segmented bottom hole assembly performs zone isolation via plug discharge after abrasive jet perforation, reducing operational time per trip.

Low molecular weight polymer composites resist shear degradation in high salinity reservoirs, sustaining sweep efficiency without excess material.

Selective affinity materials in a downhole arrangement separate oil and water, reducing the volume of produced water that requires surface disposal.

Chemical additives create gypsum crystals that generate crystallization pressure, forming dense microfracture networks while reducing water consumption.

Submerging explosive charges in wet sealant cuts tubulars into the formation, improving plug integrity while reducing operation time.

Adjustable flow control devices modify flow areas via injection fluid to optimize wellbore inflow distribution across heterogeneous formation zones.

Vibration-induced dripping creates uniform spherical ceramic proppant pellets, eliminating size distribution issues and reducing porosity for higher strength.

Spring-damper assembly absorbs mechanical shock loads during wellhead landing, preventing gasket distortion and maintaining fluid sealing integrity.

A tubless solids pump injects proppants directly into a fluid pipeline to create fracturing slurries without premixing tanks.

A shifting sleeve isolates swellable packer material from wellbore fluids until the sleeve contacts a downhole feature to expose the material.

Re-normalization technique approximates higher-order derivatives to stabilize boundary nodes and maintain uniform accuracy in hydraulic fracture simulations.

Applying dispersants to diluents reduces solvent volume needs and pressure drops in heavy crude transport pipelines.

Reactive shaped charges enlarge perforation tunnels to distribute debris uniformly, reducing flux rates and eliminating the need for mechanical sand filters.

Adjusting liquefied natural gas composition reduces miscibility pressure and eliminates water recycling costs.

A downhole flow control system separates well fluid into oil and water components using adjustable restrictors.

A straddle packer uses a velocity bypass sub to manage high-pressure fluid flow and protect internal components from solid debris.

Swellable particulate expands within proppant packs to create interconnected pores, resolving limited permeability while maintaining fracture integrity.

A biodegradable diverting agent fills well fractures using a specific particle size distribution and polyvinyl alcohol resin.

An acid gelling polymer additive thickens acidic fluids in calcium aluminate cement slurry to control fluid loss effectively.

An intermediately-mounted inflow control device distributes fluid flow evenly to resolve unbalanced distribution and screen erosion in horizontal wells.

A self-contained turbine and generator system burns extracted bitumen to generate steam and power, eliminating external energy costs.

Combining finite difference and discontinuous Galerkin methods captures sharp temperature fronts in reservoir simulations.

Polyacrylate droplets in supercritical CO2 absorb aqueous fluid to raise density, preventing gravity override during enhanced oil recovery.

Dual optimizer modules adjust control signals using real-time measurement signals to enhance accuracy of risk and reward analysis.

A reconfigurable wellhead hanger seals cables through elastomeric compression.

Silicon-free hydrophobic emulsions modify sandstone wettability from hydrophilic to oleophilic, reducing water production and improving recovery rates.

Hydraulic injection of conductive slurry powers deep electric submersible pumps without heavy cables.

Alkanolamide and alkoxylated alcohol surfactants break oil-water emulsions in subterranean formations.

Scleroglucan and diutan gelling agents maintain stable viscosity in acidic fluids up to 250°F, eliminating acid-insoluble residues from conventional polymers.