Abstract: A line is deployed along a landing string or along a marine riser of a subsea well. The line has sensors, such as temperature sensors, distributed along its length. In one embodiment, the line comprises a fiber optic line that includes fiber optic temperature sensors distributed along its length. In another embodiment, the line comprises a fiber optic line used to transmit light, wherein the returned back-scatter light is analyzed to provide a temperature profile along the length of the fiber line. The fiber optic line can be deployed by connecting it to the landing string, pumping it down a pre-existing conduit (such as a hydraulic or chemical injection conduit), or pumping it down a dedicated fiber optic specific conduit.

Abstract: A method and system used for testing a subterranean well. A sensor (34), such as a distributed temperature sensor, comprising a sensing optical fiber (48) connected to an interrogation unit (50), is deployed together with a drill stem test string (20) so that the sensor extends below the packer of the drill stem test string and across at least one formation (22) of the wellbore.

Abstract: A system to determine the mixture of fluids in the deviated section of a wellbore comprising at least one distributed temperature sensor adapted to measure the temperature profile along at least two levels of a vertical axis of the deviated section. Each distributed temperature sensor can be a fiber optic line functionally connected to a light source that may utilize optical time domain reflectometry to measure the temperature profile along the length of the fiber line. The temperature profiles at different positions along the vertical axis of the deviated wellbore enables the determination of the cross-sectional distribution of fluids flowing along the deviated section. Together with the fluid velocity of each of the fluids flowing along the deviated section, the cross-sectional fluid distribution enables the calculation of the flow rates of each of the fluids. The system may also be used in conjunction with a pipeline, such as a subsea pipeline, to determine the flow rates of fluids flowing therethrough.

Abstract: Methods and apparatus comprise a conveyance structure to carry a tool into a wellbore. The conveyance structure contains an optical fiber line to enable communication between the tool and well surface equipment. In one implementation, the conveyance structure comprises a slickline. In another implementation, the conveyance structure includes another type of conveyance device that does not convey power and data separate from the fiber optic line.

Abstract: A line is deployed along a landing string or along a marine riser of a subsea well. The line has sensors, such as temperature sensors, distributed along its length. In one embodiment, the line comprises a fiber optic line that includes fiber optic temperature sensors distributed along its length. In another embodiment, the line comprises a fiber optic line used to transmit light, wherein the returned back-scatter light is analyzed to provide a temperature profile along the length of the fiber line. The fiber optic line can be deployed by connecting it to the landing string, pumping it down a pre-existing conduit (such as a hydraulic or chemical injection conduit), or pumping it down a dedicated fiber optic specific conduit.

Abstract: A method and system used for testing a subterranean well. A sensor (34), such as a distributed temperature sensor, comprising a sensing optical fiber (48) connected to an interrogation unit (50), is deployed together with a drill stem test string (20) so that the sensor extends below the packer of the drill stem test string and across at least one formation (22) of the wellbore.

Abstract: A system to determine the mixture of fluids in the deviated section of a wellbore comprising at least one distributed temperature sensor adapted to measure the temperature profile along at least two levels of a vertical axis of the deviated section. Each distributed temperature sensor can be a fiber optic line functionally connected to a light source that may utilize optical time domain reflectometry to measure the temperature profile along the length of the fiber line. The temperature profiles at different positions along the vertical axis of the deviated wellbore enables the determination of the cross-sectional distribution of fluids flowing along the deviated section. Together with the fluid velocity of each of the fluids flowing along the deviated section, the cross-sectional fluid distribution enables the calculation of the flow rates of each of the fluids. The system may also be used in conjunction with a pipeline, such as a subsea pipeline, to determine the flow rates of fluids flowing therethrough.

Abstract: A system to determine the mixture of fluids in the deviated section of a wellbore comprising at least one distributed temperature sensor adapted to measure the temperature profile along at least two levels of a vertical axis of the deviated section. Each distributed temperature sensor can be a fiber optic line functionally connected to a light source that may utilize optical time domain reflectometry to measure the temperature profile along the length of the fiber line. The temperature profiles at different positions along the vertical axis of the deviated wellbore enables the determination of the cross-sectional distribution of fluids flowing along the deviated section. Together with the fluid velocity of each of the fluids flowing along the deviated section, the cross-sectional fluid distribution enables the calculation of the flow rates of each of the fluids. The system may also be used in conjunction with a pipeline, such as a subsea pipeline, to determine the flow rates of fluids flowing therethrough.

Abstract: Methods and apparatus comprise a conveyance structure to carry a tool into a wellbore. The conveyance structure contains an optical fiber line to enable communication between the tool and well surface equipment. In one implementation, the conveyance structure comprises a slickline. In another implementation, the conveyance structure includes another type of conveyance device that does not convey power and data separate from the fiber optic line.

Abstract: A system to determine the mixture of fluids in the deviated section of a wellbore comprising at least one distributed temperature sensor adapted to measure the temperature profile along at least two levels of a vertical axis of the deviated section. Each distributed temperature sensor can be a fiber optic line functionally connected to a light source that may utilize optical time domain reflectometry to measure the temperature profile along the length of the fiber line. The temperature profiles at different positions along the vertical axis of the deviated wellbore enables the determination of the cross-sectional distribution of fluids flowing along the deviated section. Together with the fluid velocity of each of the fluids flowing along the deviated section, the cross-sectional fluid distribution enables the calculation of the flow rates of each of the fluids. The system may also be used in conjunction with a pipeline, such as a subsea pipeline, to determine the flow rates of fluids flowing therethrough.

Abstract: Methods and apparatuses to determine the temperature profile of a wellbore using a fiber optic cable and an anchor are disclosed. Furthermore, a pressurized wellhead spool that couples to a standard Christmas tree structure on a well head to facilitate the injection of fiber optic cable into an oil and gas well is disclosed. The wellhead spool is portable and may be connected to fiber optic cable already located at the site, for quick connection to on-site instrumentation. A method of using the apparatuses disclosed to measure wellbore temperature at multiple depths of investigation is also disclosed.

Abstract: Methods and apparatuses to determine the temperature profile of a wellbore using a fiber optic cable and an anchor are disclosed. Furthermore, a pressurized wellhead spool that couples to a standard Christmas tree structure on a well head to facilitate the injection of fiber optic cable into an oil and gas well is disclosed. The wellhead spool is portable and may be connected to fiber optic cable already located at the site, for quick connection to on-site instrumentation. A method of using the apparatuses disclosed to measure wellbore temperature at multiple depths of investigation is also disclosed.