Fluid Removal TRIZ Cases

Additive supply lines dispense protective agents into wellbore flow paths to neutralize corrosive scaling substances and extend equipment life.

Expandable polymeric microparticles block high permeability zones to redirect injected fluids into unswept reservoir areas.

Finite element grids couple hydraulic fracture networks to reservoir grids, predicting microseismic events while managing computational processing time.

A subsea chemical injection system uses a low shear choke trim to minimize polymer degradation during fluid flow.

Leaching solution mobilizes minerals from shale boreholes, eliminating expensive excavation and waste displacement.

A bottom hole assembly with swelling packers provides a larger drift dimension for service string passage.

Seabed gel injection isolates cold fluid from hot production flow, preventing hydrate plugs and reducing replacement fluid volume.

A cyclic injection method displaces oil in shale formations using pressurized hydrocarbon liquids.

A vacuum or pressure method induces circumferential stresses in a swelling element packer during assembly to maintain mandrel contact.

A modular fluid flow model couples wellbore, perforation, and fracture components to simulate hydraulic fracturing pressure dynamics.

A 3D flow model predicts viscosity to suspend particulate diverting agents, preventing preferential entry into low-resistance zones.

A multi-port injection system uses a fluid return valve to route excess fluid back to measuring tubes for precise volume control.

Selected stage one and two surfactants reduce capillary pressure in small pores, improving oil flow through hydraulic fractures.

An NPT threaded brass tail plug and copper crush washer seal against gas lift valve leaks.

Internal tubes distribute fluid axially and angularly through sand screens, reducing peak velocity to prevent erosion during high-rate injection.

A temporary impermeable sleeve protects perforated well components during borehole installation.

Brine injection collapses polymer chains to lower viscosity, enabling clean phase separation without mechanical shearing.

Low-density delayed coke proppant reduces settling rates and fines production, maintaining fracture conductivity while sequestering carbon.

Self-degrading particles bridge fracture propagation near the wellbore, reducing fluid volumes and energy consumption during re-fracturing treatments.

A supervisory controller adjusts hydraulic fracturing unit flow rates and pressures using automated schedules.

A vacuum transport system moves drill cuttings through a pneumatic conduit network to a collection hub.

Segmenting the stator from the retrievable rotor-impeller reduces workover frequency while maintaining reliable electrical isolation.

Segmented decks with varying screen apertures recover wellbore strengthening materials, preventing their loss alongside cuttings.

A block copolymer coating encapsulates proppant particles to distribute crush stress and prevent fines release.

One-dimensional flow model uses connection conditions to conserve fluid momentum and mass flux at intersections.

Pressure-sensitive rupture member establishes fluid communication between isolated chambers to initiate downhole operations.

A bypass gas lift system delivers lifting gas through a single tubing string to the wellbore bottom hole.

A hydraulic sleeve valve uses a bypass relief system to provide positive position indication through fluid communication.

A multi-stage linear method extracts pressure variables from a saturation-and-pressure matrix to solve the reduced system efficiently.

Expandable casing channels direct fluid into subterranean inclusions to resolve selective extension control limits.

A compression assembly with pivotable link arms converts longitudinal force into radial expansion to deploy anti extrusion petals and packing elements.

A filter plug uses a degradable material and filtration skeleton to lodge within wellbore ports.

A conical swirl chamber creates controlled pressure drops to equalize fluid flow along horizontal wellbores.

Radial extensions on a perforated shroud disperse fluid flow velocity to reduce erosion of the filter medium caused by particle impingement.

Conductive coatings on sintered alumina proppants allow electromagnetic detection of fracture placement beyond wellbore limits.

Electrodes discharge voltage through fluid to generate pressure waves that move a piston for tool actuation.

A non-rotational cone and integral slip assembly centers the packing element within the wellbore.

A sliding sleeve valve uses swelling material to release a collet latch and redirect fluid flow.

In-situ methane hydrate formation enhances hydrostatic pressure in foamed fracturing fluids using liquefied natural gas.

Sublimating dry ice expands to disrupt the fluid column blocking hydrocarbon gas flow.

A subsea mixing module combines single-phase streams from a phase separator to create optimized multiphase flows.

A two-stage energizing material combines high explosive and reactive components to enhance energetic yield within constrained downhole tool volumes.

Transform differential pressure functions into reservoir simulator inputs for accurate hydrocarbon production modeling.

Frac stack rams control fluid flow using protective sleeves that shield seals from abrasive particles.

An inflow control device generates a predetermined pressure drop in flowing fluid using serially connected particulate screens and fluid couplings.

A viscosifying non-ionic associative polymer maintains constant viscosity under shear stress to transport proppants effectively.

Segmented geometry manages debris disposal while maintaining structural integrity during wellbore perforation.

Metal seals in the flow control hanger withstand 350°C steam pressure, preventing elastomeric failure during thermal expansion.