A water content sensor is positioned within a flowline downstream of a well-choke. The water content sensor is configured to determine a water content percentage of a production fluid flowing through the flowline. A temperature sensor is positioned downstream of the well-choke. The temperature sensor is configured to determine a temperature of the production fluid flowing through the flowline. A heating jacket surroundings at least a portion of the flowline. The heating-jacket is configured to transfer heat into the flowline. A controller is configured to receive a signal from each of the water content sensor and the temperature sensor, and control the heating jacket in response to a signal from each of the water content sensor and the temperature sensor.

A water content sensor is positioned within a flowline downstream of a well-choke. The water content sensor is configured to determine a water content percentage of a production fluid flowing through the flowline. A temperature sensor is positioned downstream of the well-choke. The temperature sensor is configured to determine a temperature of the production fluid flowing through the flowline. A heating-jacket surroundings at least a portion of the flowline. The heating-jacket is configured to transfer heat into the flowline. A controller is configured to receive a signal from each of the water content sensor and the temperature sensor, and control the heating jacket in response to a signal from each of the water content sensor and the temperature sensor.

A downhole fluid analysis tool includes a tool body, a plurality of arms coupled to the tool body and movable between a retracted position and one or more expanded positions away from a central axis of the tool body. The plurality of arms are at an angle with respect to the central axis, the angle being different in each of the one or more expanded positions. The tool further includes a plurality of fluid sensors coupled to the plurality of arms. A fluid sensor of the plurality of the fluid sensors is movably coupled to an arm of the plurality of arms and configured to pivot across a plurality of angles with respect to the arm. The angle of the fluid sensor with respect to the arm is associated with the angle of the arm with respect to the central axis of the tool body.

A downhole fluid analysis device includes a piezoelectric helm resonator, a spectroscopy sensor positioned symmetrically with respect to the piezoelectric helm resonator in at least one direction, and a circuit comprising a first terminal and a second terminal electrically coupled to a power supply. The piezoelectric helm resonator and the spectroscopy sensor are electrically coupled in parallel between the first and second terminals. The power supply drives the piezoelectric helm resonator with a voltage of a first polarity and the spectroscopy sensor with a voltage of a second polarity. The circuit includes at least one current flow control device in the circuit configured to prevent both the piezoelectric helm resonator and the spectroscopy sensor from being powered simultaneously.

A method and system of monitoring fluid flow in a wellbore. One or more space-distributed temperature input pulses are induced into at least a portion of a fluid in a housing in the wellbore. The housing has at least one cavity and one or more flow ports. A temperature response pulse, caused by the temperature input pulses, are sensed at one or more locations downstream of the cavity and a flow rate of the fluid through the cavity is determined. The flow rate may be determined based on one or more characteristics of the temperature response pulse, and a Retention Time Distribution (RTD) of the cavity.

A device which: optically detects the presence of, measures the flow rate of, and identifies the characteristics of venting fugitive gas emissions. Specifically the device provides a spectral analysis of emission gas constituents; selective detection of the presence of venting hydrocarbons; measurement of venting emissions flow rates, the measurement of shut-in and flowing venting system pressures and the venting system temperatures. The flow rates are corrected, relative to the detection of the gas constituents and standard temperature and pressure (STP). These devices are configured to collect such data electronically and transmit via various telemetry systems, to a secure remote data network for reporting, access, evaluation, real-time monitoring and archiving as required.

A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid in a semi-continuous or pulsed manner at one or more locations in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A time of flight model is used to determine, for a plurality of points of interest, a fluid flow direction, bulk flow rate and/or a cumulative flow rate contribution.

A technique includes inducing a distributed temperature change along a portion of a wellbore and measuring a time varying temperature along the portion of the wellbore due to the induced change. The technique includes determining a distributed flow rate in the portion based at least in part on the measured time varying temperature before the temperature reaches equilibrium.

A system for more accurate mechanical integrity testing of a borehole and cavity has a mechanical integrity testing tool suspended by a wireline from surface to a test depth. Distributed temperature and acoustic sensing systems respectively record distributed temperature and noise measurements along the wireline. First and second pressure sensors measure uphole and downhole pressures. The mechanical integrity testing tool has an interface detection device, which can have an Iridium-192 gamma ray source having a shorter half-life relative to conventional sources. The interface level, distributed temperature measurements, and uphole and downhole pressure measurements can be used to calculate the volume and/or mass of test fluid that has leaked out of the borehole and/or cavity over the test period. The acoustic sensing system can be used to detect and confirm the presence of a leak. The temperature and/or acoustic sensing systems can be used to identify the location of the leak.

There is described an apparatus for monitoring at least a portion of a wellbore, the apparatus comprising a body including at least an anchoring means for releasably positioning the apparatus with respect to a tubular in the wellbore. The apparatus comprises detecting means for detecting at least one parameter of a substance in the portion, and in that the apparatus comprises transceiver means configured to at least transmit data related to the parameter.