A fiber-optic cable was permanently installed along the 18 5/8-in. casing and the 21-in.-hole section of a geothermal well. During the cementing operations, the temperature was continuously recorded using distributed temperature sen. A fiber-optic cable was permanently installed along the 18 5/8-in. casing and the 21-in.-hole section of a geothermal well. During the cementing operations, the temperature was continuously recorded using distributed temperature sensing (DTS) technology to monitor the cement placement. During the drilling and injection testing phases carried out in. The DTS data acquired during a cementing operation enabled evaluation of the pumping and setting stages, showing an interval with a different thermal signature, as depicted in Figure 2. Temperature data indicate nonoptimal cement bonding. The same interval correlates with a higher CBL amplitude, which also points to nonoptimal cement bonding. This. Instead of using the traditional memory gauge tools, which require days to retrieve the data from downhole memory gauges, and a jet pump as an artificial lift system, which implies that the process data and evaluation take a long time, an operator in South America realized that this static process of collecting the data was unable to reveal unexpec. The drilling and completion of horizontal wells allows to increase the reservoir contact and thus achieve a productivity increase. This increase in horizontal length also allows the contact with heterogeneous formation, and varying reservoir properties, such as permeability and pressure, among others. Most permeable layers, under the same pressure. An operator in Mexico used the distributed temperature sensing (DTS) run with coil tubing to record temperature profiles along the carbonate reservoir being stimulated to reduce near-wellbore damage. To support the DTS system, a modular BHA containing pressure, temperature, and depth correlation sensors was deployed. In cases where high permeable c.