Multiphase flow metering is provided. In one possible implementation, a multiphase flow measurement system includes at least one reference temperature sensor at a first position configured to measure a first temperature of a multiphase flow. The multiphase flow measurement system also includes at least one heated temperature sensor at a second position downstream of the reference temperature sensor configured to excite the multiphase flow and measure a second temperature of the multiphase flow.

System and methods for optimizing flow distribution across multiple production zones are provided. A flow distribution is assigned to a plurality of production zones along a wellbore within a formation. A temperature value is estimated for each of the production zones, based on the assigned flow distribution. The estimated temperature value is compared with an actual temperature value determined for each production zone. An error amount for the estimated temperature value is calculated based on the comparison. Based on the error amount, it is determined whether or not the flow distribution has reached a global optimum. The assigning, the estimating, the comparing, the calculating, and the determining are repeated until it is determined that the flow distribution assigned to the plurality of production zones has reached the global optimum.

System and methods for optimizing flow distribution across multiple production zones are provided. A flow distribution is assigned to a plurality of production zones along a wellbore within a formation. A temperature value is estimated for each of the production zones, based on the assigned flow distribution. The estimated temperature value is compared with an actual temperature value determined for each production zone. An error amount for the estimated temperature value is calculated based on the comparison. Based on the error amount, it is determined whether or not the flow distribution has reached a global optimum. The assigning, the estimating, the comparing, the calculating, and the determining are repeated until it is determined that the flow distribution assigned to the plurality of production zones has reached the global optimum.

Apparatus (100) for use in sensing temperature in a wellbore, comprising: tubing (110) comprising a plurality of temperature sensor modules (120, 320, 420, 520, 620, 720) provided at locations along the inside of the tubing, said temperature sensor modules comprising temperature sensors (321, 421) provided at least in part by at least one semiconductor element having electrical properties that vary with temperature; an electrical network (115) configured to electrically connect to the semiconductor elements to in use allow measuring of the respective electrical properties of the semiconductor elements to infer a thermal characteristic of the semiconductor element; and at least one control module (130, 330, 430) electrically connected to multiple temperature sensor modules, via the electrical network, and configured to receive and process an electrical signal associated with the temperature sensor modules to enable inference of the temperature of the semiconductor elements and the environment to which the tubing is exposed at the location of that semiconductor element.

A measurement device is configured in a shaped charge package to be utilized in a perforating gun section tool string. The measurement device may include for example thermal conductivity detectors (TCD) configured to measure fluid flow velocity and/or thermal characteristics of the flowing fluid. The measurement device may include for example a pair laterally spaced TCDs each having sensor faces positioned co-planar with a surface across which the fluid flows. The measurement device may include a recessed TCD, having a sensor face recessed below an opening in the exterior surface.

A measurement device is configured in a shaped charge package to be utilized in a perforating gun section tool string. The measurement device may include for example thermal conductivity detectors (TCD) configured to measure fluid flow velocity and/or thermal characteristics of the flowing fluid. The measurement device may include for example a pair laterally spaced TCDs each having sensor faces positioned co-planar with a surface across which the fluid flows. The measurement device may include a recessed TCD, having a sensor face recessed below an opening in the exterior surface.

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 at a first location 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 simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

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 at a first location 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 simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

A method of determining fluid inflow locations comprises determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore, using the plurality of temperature features in a fluid inflow identification model, and determining the presence of fluid inflow at one or more locations along the wellbore based on an output from the fluid inflow identification model.

A method of determining fluid inflow locations comprises determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore, using the plurality of temperature features in a fluid inflow identification model, and determining the presence of fluid inflow at one or more locations along the wellbore based on an output from the fluid inflow identification model.