Survey TRIZ Cases

Distinguishable tracer particles release unique substances into produced fluids to identify specific subterranean locations.

A fixture assembly uses current transformers to inductively couple with a tool housing for data and power transfer.

Pressure sensor detects pulses from turbine blades passing stator flow passages to calculate mud motor rotational speed.

A downhole shifter tool assembly uses a standoff spacer to locate and anchor the device at a reference position before extending a shifting key.

Acoustic pressure waves assess fracture geometry and connected rock volume to optimize hydraulic fracturing parameters across variable geological formations.

A dual flexible bag assembly detects wellbore fluid levels by transmitting pressure changes to a sensor while isolating the sensing element from direct contact.

A minimum wellbore energy method determines optimal correction paths using real-time drilling data.

A method determines subsoil composition by associating facies to cells in an unmeshed model using parametric surfaces.

A sand control screen uses brittle functionalized fibers that break off upon particulate impact to release detectable tracer fragments into production fluid.

Addressed datagrams replace mechanical pressure signals to control downhole valves, reducing operating time and complexity in deep cased wells.

Interpolation algorithms produce finer azimuthal sampling from limited receiver arrays, enabling accurate geological feature imaging.

A data acquisition system detects core orientation by analyzing drilling parameters during extraction.

A dynamic reserve calculation method for tight gas reservoirs using corrected material balance equations.

A controller detects fluid influx by monitoring flow rates against thresholds, reducing fracture risks and operational delays in open-to-atmosphere systems.

Distributed fiber optic sensors monitor wellbore conditions to detect gas influx, resolving the trade-off between measurement precision and device complexity.

A top drive uses a proximity sensor to detect axial loading on elevators and disables the drive shaft motor rotation.

Composite insulating gaps and metallic housings block conduction currents to improve electromagnetic signal transmission efficiency.

A retrievable tubular sleeve spans wellbore washouts to enable tool passage through irregular geometries.

Segmented ring assemblies deploy independently along tubular strings to monitor time-dependent well condition changes without halting drilling operations.

Segmenting control modules along the well string positions electric actuators near devices, reducing response time and eliminating extraneous hardware.

Gamma pulse telemetry transmits encoded data via electromagnetic bursts, bypassing mud motors and agitators that block pressure pulses in extended reach wells.

A fluid pressure pulse generator uses a motor-driven valve to create precise pressure pulses in drilling mud.

Machine learning analyzes drilling parameters to estimate pore pressure, preventing blowouts and reducing non-productive time.

A Kalman filter predicts hydrocarbon production rates using decline curve and measurement models.

Wireless sensing device determines correct angular position of oil ports to eliminate manual monitoring and reduce maintenance time.

Hydraulically actuated extendable dog engages lateral boreholes to resolve window location precision and operational delay trade-offs.

Multiple neural networks reconcile noisy LWD and seismic data into consistent parameters, resolving conflicts in wellbore trajectory planning.

Acoustic sensors in the drill string separate direct and reflected signals to identify rock boundaries during vertical drilling.

A flow field measurement device uses pressure sensors to quantify gas-liquid trends in scale models.

An untethered object deploys a radially expandable metal sealing device to autonomously position itself within well passageways.

A hybrid model combines physical and statistical techniques to update input parameters dynamically, reducing screen-out risks during fracturing operations.

Acoustic telemetry transmits sensor data through corrosive fluids, bypassing electrical limitations in offshore drilling.

Multi-frequency complex impedance analysis identifies low water concentrations in drilling flows, reducing filter wear and frequent maintenance cycles.

Actuating seismic sources in offset wellbores detects reflected energy to determine geodetic positions, improving accuracy at lateral distances.

Tangential fiber mating prevents debris accumulation and buckling in harsh downhole environments.

Sensor modules with accelerometers detect lateral movement to reduce stress on drill strings during drilling operations.

Segmented electromagnetic coils detect lateral displacement and axial position of drill strings, enabling blow-out preventers to seal off-center pipes.

Real-time sensor feedback optimizes diluent injection and pump speed, minimizing fluid consumption while maintaining efficient heavy oil production.

A stuck pipe adapter applies tension to diagnose well anomalies while a machine learning algorithm predicts the exact location of the event.

A debris barrier reduces particulate transport into a sensing link, maintaining measurement precision despite debris accumulation.

Segmented metal tubes align photons with pixelated scintillators, resolving position sensitivity and cost trade-offs in downhole imaging.

Segmented wireless sensor assemblies decouple from the logging tool to measure fluid pressure and flow without obstructing downhole circulation.

A computational system calculates elastic and crushed foam volume changes to simulate annular fluid expansion in a wellbore.

Real-time pressure feedback enables variable speed control, resolving the contradiction between maintaining constant velocity and maximizing productivity.

A downhole base gauge queries remote sensors in series via a single control line, resolving space constraints and power limitations.

A multi-parameter fiber optic cable integrates strain, temperature, and acoustic sensing into a single deployable unit.

An insulative base fluid maintains treatment slurry temperature during transport to preserve additive integrity.

A pulsed-neutron logging method computes the ratio of inelastic to capture count rates to determine formation porosity.