A bubble measurement system includes a bubble detector including a vessel having a flow path configured to receive a flow of fluid including air bubbles from a bubble generator and an imaging system. The imaging system includes an imaging device for imaging the fluid and air bubbles in the flow path of the vessel of the bubble detector. The imaging system has an imaging controller coupled to the imaging device and receiving images from the imaging device. The imaging controller processes the images to measure bubble size of each air bubble passing through the bubble detector. The imaging controller includes a pairing module comparing successive images and the air bubbles in successive images to measure all bubbles flowing through the vessel.

A bubble measurement system includes a bubble detector including a vessel having a flow path configured to receive a flow of fluid including air bubbles from a bubble generator and an imaging system. The imaging system includes an imaging device for imaging the fluid and air bubbles in the flow path of the vessel of the bubble detector. The imaging system has an imaging controller coupled to the imaging device and receiving images from the imaging device. The imaging controller processes the images to measure bubble size of each air bubble passing through the bubble detector. The imaging controller includes a pairing module comparing successive images and the air bubbles in successive images to measure all bubbles flowing through the vessel.

A multiphase flow calibration semi-closed loop system includes an oil-gas-water separation unit, a multiphase flow calibration unit, a single phase flow calibration section, a gas flow section, a flow data acquisition unit, and a programmable logic controller (PLC). The system is designed to have a two-step calibration process. In a first step, single phase water flow meters and single phase oil flow meters of the system are calibrated independently. In a second step, multiphase flow meters or multiphase water cut meters are calibrated using the pre-calibrated water flow meter, pre-calibrated oil flow meter, and the pre-calibrated gas flow meter. In doing so, the oil-gas-water separation unit, the multiphase flow calibration unit, the single phase flow calibration section, and the gas flow section communicate with the flow data acquisition unit providing real time data. Thus, the PLC connected to the flow data acquisition unit can perform the required calibration processes.

Methods for determining phase fractions of a downhole fluid via thermal properties of the fluids are provided. In one embodiment, a method includes measuring a temperature of a fluid flowing through a completion string downhole in a well and heating a resistive element of a thermal detector at a position along the completion string downhole in the well by applying power to the resistive element such that heat from the resistive element is transmitted to the fluid flowing by the position. The method also includes determining, via the thermal detector, a flow velocity of the fluid through the completion string and multiple thermal properties of the fluid, and using the determined flow velocity and the multiple thermal properties to determine phase fractions of the fluid. Additional systems, devices, and methods are also disclosed.

Methods for determining phase fractions of a downhole fluid via thermal properties of the fluids are provided. In one embodiment, a method includes measuring a temperature of a fluid flowing through a completion string downhole in a well and heating a resistive element of a thermal detector at a position along the completion string downhole in the well by applying power to the resistive element such that heat from the resistive element is transmitted to the fluid flowing by the position. The method also includes determining, via the thermal detector, a flow velocity of the fluid through the completion string and multiple thermal properties of the fluid, and using the determined flow velocity and the multiple thermal properties to determine phase fractions of the fluid. Additional systems, devices, and methods are also disclosed.

Methods and apparatus for hydrocarbon monitoring are provided. A method that may be performed by a flowmeter or monitoring system includes receiving downhole measurements of a flowing fluid from a flowmeter; determining a standard phase fraction of the flowing fluid based on the downhole measurements from the flowmeter; receiving surface measurements of the flowing fluid; determining a surface phase fraction of the flowing fluid based on the surface measurements; comparing the standard phase fraction to the surface phase fraction; based on the comparison being greater than a predetermined threshold, using the surface measurements as a reference to adjust a speed of sound (SoS) of a first phase until a target value is achieved; and receiving additional downhole measurements of the flowing fluid from the flowmeter, wherein the flowmeter is operating using the adjusted SoS of the first phase.

Methods and apparatus for hydrocarbon monitoring are provided. A method that may be performed by a flowmeter or monitoring system includes receiving downhole measurements of a flowing fluid from a flowmeter; determining a standard phase fraction of the flowing fluid based on the downhole measurements from the flowmeter; receiving surface measurements of the flowing fluid; determining a surface phase fraction of the flowing fluid based on the surface measurements; comparing the standard phase fraction to the surface phase fraction; based on the comparison being greater than a predetermined threshold, using the surface measurements as a reference to adjust a speed of sound (SoS) of a first phase until a target value is achieved; and receiving additional downhole measurements of the flowing fluid from the flowmeter, wherein the flowmeter is operating using the adjusted SoS of the first phase.

An optical sensor device configured for use in combination with a fluid flowing through a tubing, the optical sensor device includes a light source configured to emit a light, with at least a portion of the light being exposed to a fluid in the tubing and reflected, an optical sensor configured to receive at least a portion of the reflected light and analyze at least a portion of the received reflected light to determine a reflectance measurement, and a controller configured to correlate the reflectance measurement to an input particulate level and generate an output indicative of the fluid flow rate corresponding to the reflectance measurement. Also disclosed is a method of optically measuring fluid flow rate in a fluid processing system including optically monitoring fluid flow through a transparent portion of a tubing by measuring light reflectance of particles in the fluid.

A concentration sensor assembly can include a vaporization chamber having a compound. The concentration sensor assembly may include a first flow path coupled to the vaporization chamber. The first flow path may direct a first gas to the vaporization chamber. A second flow path can direct a second gas out of the vaporization chamber. The second gas can include the compound and the first gas. A first sensor is disposed along the first flow path. The first sensor measures first data indicative of a first mass flow rate of the first gas. A second sensor is disposed along the second flow path. The second sensor measure second data indicative of a second mass flow rate of the second gas. A computing device may determine a concentration of the vaporizable substance within the second gas based on the first data and the second data.

A concentration sensor assembly can include a vaporization chamber having a compound. The concentration sensor assembly may include a first flow path coupled to the vaporization chamber. The first flow path may direct a first gas to the vaporization chamber. A second flow path can direct a second gas out of the vaporization chamber. The second gas can include the compound and the first gas. A first sensor is disposed along the first flow path. The first sensor measures first data indicative of a first mass flow rate of the first gas. A second sensor is disposed along the second flow path. The second sensor measure second data indicative of a second mass flow rate of the second gas. A computing device may determine a concentration of the vaporizable substance within the second gas based on the first data and the second data.