Fluid Removal TRIZ Cases

Polyvinyl alcohol resin particles fill fractures and dissolve via hydrolysis, resolving low-temperature biodegradation bottlenecks.

Alternating flow direction injects compositions from distinct locations to form reaction products that reduce permeability in target regions.

Formulating diluted microemulsions with specific solvents reduces capillary pressure to overcome water blocks in gas well rock formations.

Segmented high and low pressure dart pairs maintain sealing integrity across 100 to 10,000 psi ranges without plastic deformation.

A magnetic retrieval tool engages fluid lift plungers for controlled insertion and extraction in wellhead lubricators.

A wellbore turbine converts hydrostatic pressure into rotational mechanical energy via a helical rotor.

Composite slugs resolve the trade-off between microscopic displacement and areal sweep efficiency while cutting operating time.

A vertical tower with a swinging telescopic boom replaces horizontal trailers, reducing well site footprint while maintaining high-capacity proppant storage.

A hydrodynamic flow device circulates gravel slurry through a tubular member in open hole wellbores.

Injecting a surface-heated hydrocarbon and steam mixture reduces viscosity in thin heavy oil reservoirs while minimizing heat loss to overburden.

CFD and DEM modeling customizes degradable polymer particles to maximize pressure build-up while minimizing formation damage risks.

Graded packing material between screens retains formation sand, preventing plugging from poor injection water quality.

A removable plug and permeability poison create a longitudinal fluid seal within gravel packed wells to isolate specific production zones.

A cross-linked polymer emulsion flooding fluid maintains viscosity and shear resistance during injection into subterranean formations.

Zeta potential altering compositions form deformable coatings on proppants to increase aggregation and agglomeration propensities.

Downhole flow control devices manage fluid movement through isolated wellbore zones to restrict hydrocarbon co-production and optimize lithium brine yield.

A downhole valve device uses a movable sleeve and burst element to control reservoir access through tubular bores.

A swellable seal system expands within a wellbore liner-hanger tie-back assembly to create a reliable fluid and pressure barrier.

A composite ball sealer uses a disintegrable polyester core and impact-resistant coating to withstand high-pressure fracturing loads.

A downhole cyclone separator uses a rotating screw to direct liquid radially outward and gas inward through distinct passages.

A crosslinked fluid uses a biopolymer gelling agent to deliver stable viscosity and improved proppant transport.

A concentric tubular insert creates separate flow paths for simultaneous production from multiple zones without fluid commingling.

A double filter cake isolates wellbore intervals using sequential slurry pumping with degradable and non-degradable particulates.

A downhole fluid composition uses a sequestering agent to inhibit an oxidative breaker until hydrocarbon contact or elevated temperatures trigger gel breakdown.

Initial propellant fires before shaped charges to displace well fluid from the annular region.

Labile synthetic polymers decompose under downhole conditions to reduce formation damage and operational costs.

An explosive-free perforation tool creates larger openings in production strings to enable sealing composition injection.

Reversible pumps draw fluid from downstream sections to isolate leaks, preventing environmental damage without full system shutdown.

Fluid pressure shifts the sleeve insert to enable simultaneous multi-zone fracturing.

Segmented leak off tubes draw carrier fluid from gravel slurry to enable dehydration across blank pipe sections, preventing voids in the gravel pack.

A perforating assembly uses a magnetic shape-memory alloy to activate and deactivate its fire control circuit via external magnetic fields.

A subsea separator uses a moving piston to separate mixtures by gravity, reducing operational costs in challenging underwater environments.

A cut-and-pull spear mechanism grips tubulars under tension to enable multiple cuts in a single wellbore trip.

A wellbore completion string with master and slave activatable stimulation assemblies coordinates fluid communication across multiple zones.

Resin-hardened proppant pillars withstand high closure stress, reducing costs by 33% and minimizing fine migration.

Ether-based solvent compositions replace toxic aromatics to remove oily residues, ensuring environmental safety while maintaining high flash points.

Graphene-based filter material removes ions from downhole fluid to prevent ion interference and maintain packer swelling efficiency.

Pyrolysis of adjacent kerogen increases subsurface pressure and permeability, enabling economic production from formations lacking natural drive.

A cross-linked polymer encapsulated in a protective shell modifies subterranean formation permeability through controlled hydrogel formation.

An in-situ formation property measurement tool deploys sensors and fluid injection systems directly into a borehole to determine geological characteristics.

A fluid flow control system uses a turbine and inflow device to manage production pressure differentials.

Low-density petroleum coke gravel packing resolves transport difficulties and high viscosity carrier fluid requirements while maintaining high crush strength.

A galvanic time release plug uses an electrochemical cell to dissolve a flow blocking device in a well passage.

Stamped metal dehydrator screen with punched openings directs carrier fluid from gravel pack slurry to base pipe screens.

Segmenting drainage fluids into semi-localized zones and modulating pump speeds to retain gas-phase solvent within the reservoir, reducing solvent bottlenecks.

Hydrophilic colloidal particles in a polymer matrix allow instant swelling and un-swelling, reducing rig time compared to conventional materials.