We listen to the well, read its temperature and model the flow
Fibre turns the whole wellbore into a sensor, and CFD explains why the flow behaves as it does. We are building the chain: test rig, raw data, simulation, field.
The whole wellbore as one sensor
Pick a scenario. The schematic, acoustics and temperature share one depth axis, so an event shows up in all three views. The RAW button shows what an interpreter actually works with.
DAS · Distributed Acoustic Sensing
A laser sends pulses down the fibre and an interrogator measures the phase of the Rayleigh backscatter. Sound and vibration strain the fibre, so every section acts as a microphone.
DTS · Distributed Temperature Sensing
Temperature comes from Raman scattering: the ratio of the anti-Stokes and Stokes components depends on the fibre temperature at each point.
Instead of a point reading
Inflow profile, tubing leaks, behind-casing crossflow, frac monitoring and pump behaviour, along the whole well and over time.
From raw data to an interpretation you can trust
DAS produces huge volumes of RAW data, and it is easy to see things in it that are not there. So we plan rig tests with a controlled leak and inflow: the truth is known in advance, and the algorithm can be checked honestly.
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Rigfibre, controlled leak and inflow02
RAW dataunprocessed interrogator records03
Processingnoise, frequency bands, features04
Interpretationchecked against the known rig state05
NEXORA moduleafter validation, on customer dataPlanned Rig tests and RAW data interpretation are planned. Engineering studies on customer data are possible today; the platform module follows rig validation.
We simulate the flow, then check it against reality
Below is a real solver: the flow equations run right on your device. Change the inlet velocity or geometry, and the flow field rebuilds itself.
The demo shows the principle on a 2D model at a teaching Reynolds number. Engineering studies use industrial packages (OpenFOAM, Ansys) on 3D multiphase models calibrated to field data.
Multiphase flow
Flow regimes, slugging, phase distribution in pipes and vessels.
Erosion and water hammer
Where and why metal wears out, which transients are dangerous.
Separators and pumps
Residence time, carry-over, pump stage behaviour on real fluid.
CFD on real data, not on assumptions
We plan to build a lab and test rigs to calibrate CFD models on real measurements. The same leak is simulated in CFD, recorded by fibre on the rig and then searched for in well data.
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CFD modelpredicts the event signature02
Rig and labmeasure the same event03
Calibrationthe model matches the measurement04
Fieldfinding the event in customer dataWRA starts to listen: acoustics and instrument screens
Today WRA identifies the fish from a photo of the impression block. Under R&D we are adding acoustic data and instrument screenshots to the model, so its conclusion rests on several independent sources.
Impression photo
Working: 99.48% average confidence in field trials on 7 fields.
Acoustic data
R&D: the acoustic signal as an additional indicator of wellbore condition.
Instrument screenshots
R&D: reading values from screenshots when a data export is not available.
What is worth clarifying
Does the well need new fibre?
Fibre access is needed: permanently behind casing or on a cable run in for the survey. The option depends on the well design and goal, and is chosen at the assessment stage.
Can a study be ordered today?
Yes, CFD and engineering studies are offered as a service on customer data. Platform modules follow rig validation.
What happens to our data?
We sign an NDA before any data changes hands. Processing can run on your servers.
Got a well where it is unclear what is going on?
Describe the problem: we will say what DAS, DTS or CFD can give you, and whether it is worth doing.