DTS acquisition system
Acquire distributed temperature data from deployed optical fiber to help improve well production or injection.
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.
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.
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.
Current state of the art of distributed time- and depth-based temperature analysis used with our DTS systems.
A data interpretation platform helps identify out-of-zone injection (OOZI) and assess whether injected water has been rerouted from the reservoir to some other sink.
More than 1,800 permanent installations, more than 18.5 million ft [5.64 million m] of fiber, and a life span of more than 10 years.
A new distributed temperature sensing (DTS) interpretation method used in horizontal injection wells characterizes static facies and highlights independent features called thermofacies.
Operator increases gas storage capacity and meets peak gas demand.