Fluid Removal TRIZ Cases

A slickline-conveyed tubing cutter uses a progressive cavity motor to rotate blades and cut tubular strings in confined wellbores.

A downhole steam generator uses distinct shear points to manage mechanical loads during wellbore deployment.

A spring-biased valve system adjusts operational force through degradable connections to maintain closure.

Low molecular weight polyethylene glycol coatings prevent respirable dust formation, maintaining particle size and productivity.

An interwell connectivity model correlates gas injection inputs with hydrocarbon production outputs to optimize extraction efficiency.

A pressure intensifier uses stacked pistons to boost fluid pressure for downhole tubular morphing operations.

A degradable plug system uses a magnesium alloy core to form a fluid-tight seal in downhole tubulars.

Automated pump speed and valve control maintains continuous proppant concentration and flow rate, eliminating discrete step-wise adjustments.

Admixing divalent cations with polymer solutions increases fluid viscosity for subterranean treatment operations.

Integrated spearhead acid injection with perforation reduces water consumption and equipment time per stage while maintaining corrosion protection.

A coupled reservoir-pipe flow model determines well pressures and flow rates using a linear iterative solver.

A downhole vibratory bypass tool protects against abrasive damage by diverting fluid via a pressure-actuated screen until activation.

A contact seal plug prevents fluid migration from igniter holders during explosive charge firing, protecting neighboring tool string components.

Reduced pseudo-component fluid models correlate gas condensates via equation of state relationships, eliminating extensive PVT data requirements.

A detonation interrupt device uses a movable mechanical member to separate explosive train components during transport.

Segmented hollow proppants maintain neutral buoyancy to penetrate deep fractures, eliminating thickening agents that reduce formation permeability.

A modular perforating gun uses a pre-wired initiator assembly to streamline downhole deployment.

Estimates fracture complexity using real-time pressure and micro-seismic signals to calculate observed growth rates.

Segmented flow control devices maintain steam trap integrity while reducing vertical well spacing and startup time.

Micro-bubbles attach to hydrophobic sand particles to provide buoyancy, preventing rapid settling in water without requiring viscous polymer additives.

Chemical degradation accelerators swell and hydrolyze degradable polymers in wellbores, resolving slow breakdown rates at varying temperatures.

Supplementing immiscible water injection cycles with nutrients stimulates resident microorganisms to alter three-phase relative permeability.

Segmented safety sleeve activates under differential pressure to maintain seal contact without increasing expansion pressure.

Degradable solid particulates bridge proppant pack pore throats to divert fracturing fluid into deeper formation zones.

A low-salinity water injection fluid combined with a viscosifying polymer enhances reservoir sweep efficiency and displaces trapped oil.

A downhole stimulation device uses a shaped charge initiator to ignite energetic material along its length.

A temporary plugging agent composed of acrylamide and laponite provides high-temperature resistance.

A progressive cavity pump stator features a seating mandrel and seal element forming a static seal with the tubing string.

A mill guiding device directs a cutting tool toward a target casing, preventing lateral movement during intersection and ensuring precise fluid connection.

A slotted basket attached below a retrievable bridge plug captures broken sealing element segments during well operations.

Ion-exchange treatment imparts compressive stress to spherical glass particles, preventing fine fragment generation that blinding well interstices.

Dense ceramic discs with uniform spacers maintain 0.2-0.5 mm gaps, preventing clogging while resisting abrasion and bending stress in boreholes.

A water-based treating fluid composition uses a hydrogen peroxide and ferrous ion mixture to degrade biopolymers.

Chemical reaction between ammonium and nitrite compounds generates nitrogen gas to form stable foam, eliminating external gas injection energy.

Isolating production wells with low-permeability strata enables independent in situ combustion heating across separate oil-bearing layers.

A consolidating treatment fluid stabilizes formation particulates in injection wells using a base fluid and tackifying agent.

Modified lower cone ramp angles prevent fin contact, eliminating premature slip shearing for consistent radial expansion.

A movable flow diverter assembly pivots to restrict fluid flow through a valve inlet based on density changes.

Single-trip well completion uses abrasive jet perforation and fluid-displaced plug substances to eliminate time-consuming packer setting across multiple zones.

Alternating foam and base fluid injections form faster flow channels, reducing water usage and formation damage.

A modified horizontal Christmas tree acts as a flow base to divert fluids from a damaged wellhead via a capping stack and conduit.

A surge immune liner setting tool uses a bypass passage to manage pressure surges and ensure controlled operation of the hanger setting mechanism.

Magnetic composite proppant creates cohesive bridges to prevent particulate flow-back while maintaining hydrocarbon permeability.

Integrates drilling and fracturing operations using temporary isolation fluid to create fractures during the drilling process.

Alkylaromatic sulfonates with broad alkyl chain distributions solubilize waxy crude oils across varying reservoir salinity conditions.

Expandable diverting agents seal flow channels by dynamically adjusting volume, preventing fluid diversion into dominant channels.

A water-based friction reducing additive combines a polymer and suspension agent to lower fluid viscosity.