WellWatcher BriteBlue Multimode DTS Fiber | Schlumberger

WellWatcher BriteBlue

Multimode DTS fiber

Enhance production management with real-time fiber-optic reservoir surveillance

Improve recovery by rapidly identifying—and responding to—changes in reservoir flow from distributed temperature sensing (DTS) using the WellWatcher BriteBlue multimode DTS fiber in applications up to 347 degF [175 degC]. 

Our fiber-optic technology enables you to monitor downhole distributed temperature profiles at the surface in real time. You can also transmit the data to your digital oilfield platform or other locations via satellite, Internet, or cable, so you can immediately identify the time, location, and reasons for changes in flow.

The result: Reduced downtime and deferred production because you can react more quickly to detrimental events, and cost savings because you can precisely identify the problem. 

Schlumberger Worker Reviewing Distributed Measurement Systems Data
Enhance Your Unconventional Field Strategy with Fiber Optics
When you deploy optical fiber in several wells as part of your unconventional field development program, you’re investing in long-term knowledge about your wells and reservoir.
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Schlumberger Worker in Manufacturing Facility

Simplify fiber delivery and economics

The optical fiber can be pumped through a conduit using Schlumberger patented techniques to provide a cost-effective DTS system suitable for high-volume applications. The conduit is hung from the surface across the interval of interest, and the temperature of the entire wellbore is monitored. 

Downhole distributed temperature profiles can be monitored at the surface in real time; data can also be transmitted to multiple remote locations. Consequently, anomalies such as loss of tubing, casing, or cement integrity or malfunctioning gas lift valves can be immediately recognized and remedial actions planned. 

Enhance lifetime in hydrogen environments

Conventional DTS-fiber temperature ratings do not take into account the degradation of the fiber when it is exposed to high levels of hydrogen (e.g., in SAGD wells), especially at high temperatures. Schlumberger pioneered accelerated aging tests for optical fibers at high temperatures. The fiber resulting from this research demonstrated an almost 50-fold increase in light transmission, exceptional resistance to hydrogen, longer life, faster response times, and better spatial resolution.

Metris Eclipse
Combining a robust, reliable Metris Evolve gauge with inductive coupler technology for wireless power and data transmission, the Metris Eclipse B-annulus PT monitoring system enables continuous well integrity monitoring behind the production casing in subsea wells.
Metris Extreme
These HPHT permanent PT gauges have advanced quartz sensors for high-quality measurements in the tubing or annulus. They are rated up to 30,000 psi [207 MPa] and 400 degF [204 degC].
Metris Evolve
These permanent PT gauges use proprietary enhanced silicon-on-insulator (eSOI) sensors for high-quality measurements in the tubing or annulus. They are rated up to 16,000 psi [110 MPa] and 302 degF [150 degC].
Unconventional well stimulation
Using WellWatcher Extend high-resolution dual-sensor PT gauges in unconventional oil and gas wells to monitor bottomhole pressure helps in identifying significant changes to skin, degradation of fracture size and conductivity, and stress-related permeability behaviors. Proactively analyzing the data enables you to monitor drawdown during production and the health of the fractures, both of which are important for long-term well performance.

Distributed permanent measurement acquisition hardware and software

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  • Surface hardware
  • Downhole hardware
  • Acquisition software
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