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PROBE™ Multilayer Downhole Monitoring System
One tool. Continuous, real-time zonal pressure, temperature, flowrate, and water cut for every producing interval — without additional cables, downhole interventions, or repeated wireline logging runs.
Overview
Overview
PROBE is a compact downhole monitoring tool that provides continuous measurement of the four key reservoir parameters — pressure (P), temperature (T), total liquid flowrate via spinner (Q), and water cut via capacitance sensor (WC) — from each individual producing zone in a multilayer well. Tools are installed directly above each producing formation, providing independent measurement of inflow from every interval without interference from adjacent zones.
Managing production from multilayer wells demands accurate, continuous knowledge of what each zone is contributing. Periodic well logging provides only discrete snapshots — at high cost per run. PROBE was developed to solve this, transmitting live data to surface or recording it autonomously downhole.
This versatility means PROBE can serve as both a long-term reservoir monitoring solution and a real-time production management tool in ESP-equipped wells, with no additional workover required for integration. The first deployment of this technology in Kazakhstan was performed by AB Smart Services at the Arystanovskoye field.
Two deployment modes
PROBE operates in two modes, both without additional downhole cable, surface cable, or infrastructure modification:
- Memory mode
Run on slickline, records high-resolution data autonomously for up to 388 days at 1-second sampling before retrieval. No additional cables, surface modifications, or workover required.
- Real-time mode
Integrates into existing ESP completions and transmits live zonal data to surface through the existing ESP power cable. All data streams into a cloud-based analytics platform for continuous remote monitoring by the operator's team.
Specifications
| Parameter | Value |
|---|---|
| Pressure sensor type | Sapphire crystal |
| Pressure accuracy | ±0.02% |
| Pressure resolution | 0.015 psi |
| Temperature sensor type | Platinum RTD |
| Temperature accuracy | ±0.01°C |
| Temperature resolution | 0.003°C |
| Flowrate measurement | Bi-directional spinner |
| Flowrate range | 19 – 7,550 bbl/day |
| Impeller diameter | 2.4 inches |
| Water cut sensor type | Capacitance |
| Water cut range | 0 – 100% |
| Water cut accuracy | ±1% |
| Parameter | Value |
|---|---|
| Operating pressure | 11,600 psi (80 MPa) |
| Operating temperature | Up to 150°C |
| Tool length | 3.6 ft (1.1 m) |
| Tool weight | 12.8 lbs |
| Battery life (memory mode) | Up to 388 days at 1-second sampling |
| H₂S resistance (standard) | 6% |
| H₂S resistance (optional) | 25% |
| Deployment method | Slickline (memory) or ESP cable integration (real-time) |
| Additional cable required | None — uses existing ESP power cable |
Specifications as published by AB Smart Services; values may be revised as equipment is upgraded.
Applications
- Continuous zonal production monitoring from each reservoir layer — identifying which zones are contributing and in what proportion
- Real-time production profiling below ESP systems — enabling immediate optimisation of pump operating modes
- Early detection of water breakthrough and reservoir pressure changes before they become costly production problems
- Rate Transient Analysis (RTA) and well interference studies using high-resolution continuous pressure data
- Improved reservoir management and field development planning based on actual zonal inflow data rather than periodic snapshots
- Replacement of Y-Tool setups and periodic PLT operations — eliminating repeated wireline runs, personnel mobilisation, and associated OPEX
Economic benefits
- No additional downhole cable or infrastructure required — uses existing ESP power cable
- No workover required for integration into existing ESP completions
- Eliminates repeated PLT runs, personnel mobilisation costs, and associated OPEX
- Continuous data enables proactive reservoir management and reduces costly unplanned interventions
Best suited for
- Multilayer wells where zonal production split is unknown or uncertain
- ESP-equipped wells requiring real-time production profiling
- Fields where periodic PLT programmes represent significant recurring cost
- Operators seeking to optimise ESP performance and extend pump run life
Field evidence
Discuss this technology
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