Abstract: Multiphase flowmeters and related methods are disclosed herein. An example apparatus includes a flowmeter and a fluid conduit to provide a flow path for a fluid relative to the flowmeter. The example apparatus includes a sensor coupled to the fluid conduit to generate data indicative of at least one of a presence, an absence, or a mass flow rate of solids in the fluid during flow of the fluid through the fluid conduit. The example apparatus includes a processor. The sensor is to be communicatively coupled to the processor. The processor is to selectively determine flow rates for one or more phases of the fluid based on data generated by the flowmeter and a first algorithmic mode or a second algorithmic mode selected based on the sensor data.

Abstract: In accordance with some embodiments, a method of placing unique particulate tracers in a subterranean formation having a wellbore therewithin is disclosed. In accordance with some embodiments, a system of placing unique particulate tracers in a subterranean formation having a wellbore therewithin is disclosed. In accordance with some embodiments, a method of determining a fraction of a stage in which to place a unique particulate tracer is disclosed.

Abstract: A method for determining the real-time concentration of hydrogen sulfide from mudlogging data using artificial intelligence, during a drilling operation, and adjusting drilling operations accordingly. The method includes obtaining mudlogging data while conducting a drilling operation and processing the mudlogging data with an artificial intelligence (AI) model to determine a predicted quantity of hydrogen sulfide. The method further includes determining a drilling operation condition based on the predicted quantity of hydrogen sulfide and adjusting, based on the determined drilling operation condition, the drilling operation. The method further includes determining a completions plan and a production plan for operating a well based on the predicted quantity of hydrogen sulfide.

Abstract: A microfluidic device includes a substrate having a first fluid inlet/outlet system, a second fluid inlet/outlet system, and a fluidic network between the first fluid inlet/outlet system and the second fluid inlet/outlet system and in fluid communication with the first fluid inlet/outlet system and the second fluid inlet/outlet system. The fluidic network includes a microfluidic channel network that is in fluid communication with the first fluid inlet/outlet system and spaced from the second fluid inlet/outlet system, a nanofluidic channel network fluidly connecting the microfluidic channel network and the second fluid inlet/outlet system, and a plurality of pores in fluid communication with the microfluidic channel network and the nanofluidic channel network.

Abstract: A method to produce in-situ steam comprising the steps of producing a laser beam in a steam generator segment positioned in a wellbore in a formation; introducing the laser beam to an activated carbon container, where the activated carbon container comprises activated carbon; increasing a temperature of the activated carbon with the laser beam to produce a hot activated carbon; introducing water to the activated carbon container through a water supply line; producing steam in the activated carbon container when the water contacts the hot activated carbon; increasing pressure in the activated carbon container as steam is produced until a pressure set point of an inter-container valve is reached; releasing steam through the inter-container valve to a steam container; increasing a pressure in the steam container until a release set point of one or more release valves is reached; and releasing steam through the release valve to the formation.

Abstract: Gas and liquid velocities of fluid in a lift gas assisted well system are estimated by adding liquid and gas tracers downhole and monitoring their travel time over a known distance. Based on estimated velocities, a slip factor is obtained that represents relative velocities of the gas and liquid in the fluid. A flow regime of the fluid is identified based on the slip factor. The flow regime is optionally altered by adjusting one or more operational parameters of the well.

Abstract: An apparatus for determining, by electrical tomography, vertical profile of an electrical property of interest of material(s) in a target volume comprises a measurement probe to be positioned at a plurality of different measurement levels in a target volume and comprising a plurality of measurement elements each having an interface surface. Each interface surface has a size, shape, and rotational position. A measurement path is formed between two interface surfaces as dependent on the sizes, shapes, and rotational positions of the two interface surfaces, and the distance between the two interface surfaces. The locations, rotational positions, shapes, and sizes of the interface surfaces are selected to provide at least two different measurement paths differing from each other in one or more of said sizes of, shapes of, rotational positions of, and distances between the associated interface surfaces.

Abstract: Liquid is unloaded from a well with a hybrid gas lift system that includes a lift gas source and valves for injecting lift gas into production tubing. The types of valves include pressure production operated (“PPO”) valves and a surface operated valve. Pressure inside the production tubing is measured to monitor operation of the PPO valves, and identify if the PPO valves are experiencing and anomaly, such as multi-pointing or chattering. The surface operated valve is selectively actuated to correct anomalous operation of the PPO valves.

Abstract: Downhole plugs including a sensor, hydrocarbon wells including the downhole plugs, and methods of operating the hydrocarbon wells. The downhole plugs include a sealing structure, an actuation mechanism, and the sensor. The actuation mechanism is configured to selectively transition the sealing structure between a disengaged state, in which the downhole plug is free to move within a tubular conduit of a downhole tubular of the hydrocarbon well, and an engaged state, in which the sealing structure operatively engages with the downhole tubular, forms a fluid seal with the downhole tubular, and resists motion of the downhole plug within the tubular conduit. The sensor is configured to detect a sensed parameter within the tubular conduit and to generate a sensor signal indicative of the sensed parameter.

Abstract: Monitoring and diagnosing completion during hydraulic fracturing operations provides insights into the fracture geometry, inter-well frac hits and connectivity. Conventional monitoring methods (microseismic, borehole gauges, tracers, etc.) can provide a range of information about the stimulated rock volume but may often be limited in detail or clouded by uncertainty. Utilization of DAS as a fracture monitoring tool is growing, however most of the applications have been limited to acoustic frequency bands of the DAS recorded signal. Low-frequency Distributed Acoustic Sensing (DAS) signal is used to constrain hydraulic fracture geometry. Events like fracture opening and closing, stress shadow creation and relaxation, ball seat and plug isolation can be clearly identified.

Abstract: A first flow distribution to one or more entry points into a subsurface formation may be monitored. Stimulation criteria may be identified based on the first flow distribution. At least one characteristic associated with a first treatment fluid to be injected into a wellbore associated with the subsurface formation may be determined based on the first flow distribution, where the at least one characteristic is based on the stimulation criteria. The subsurface formation may be stimulated with the first treatment fluid and a second flow distribution monitored based on the stimulation. A determination is made whether the second flow distribution meets the stimulation criteria. The subsurface formation may be stimulated with a second treatment fluid based on the determination that the second flow distribution does not meet the stimulation criteria.

Abstract: A method of identifying and diagnosing open gas lift valves in a gas lift production well, the gas lift production well including a production tubular having a plurality of mechanical gas lift valves, and a casing surrounding a portion of the tubular to form an annulus. The method includes reducing injection pressure below the minimum design opening pressure of each of the plurality of mechanical gas lift valves to close each of the plurality of mechanical gas lift valves; incrementally increasing injection pressure to operating or designed injection pressure to sequentially open one or more of the plurality of mechanical gas lift valves; measuring pressure, amplitude, frequency and/or wave patterns produced by the sequential opening of the one or more mechanical gas lift valves; and determining the location of the one or more mechanical gas lift valve locations.

Abstract: A system and method for logging in a wellbore where sensor assemblies on a logging tool are deployed and landed in the wellbore. After the sensor assemblies are landed in the wellbore and released from the logging tool, the logging tool is pulled uphole. Moving the logging tool uphole from where the sensor assemblies are landed, reduces interference of the logging tool with measurements obtained with the sensor assemblies. The sensor assemblies include sensors for detecting fluid flow, pressure, temperature, fluid density, formation resistivity, and which can be mechanical, optical, acoustic, or electromagnetic.

Abstract: Systems, methods, and computer-readable media for forecasting a time to complete a simulation of a reservoir simulation model. A processor can run a simulation of a reservoir simulation model for a first predetermined period of time associated with a first computation step of the simulation. The processor can measure a performance result of the simulation for the first predetermined period of time. The performance result can include an elapsed wall clock time and a timespan simulated. The processor can then forecast a remaining time to complete the simulation of the reservoir simulation model based on the performance result.

Abstract: Interaction of adsorbing chemicals with a downhole tool presents inaccuracies in the adsorbing chemical measurement and analysis. The principles of the present disclosure provide a method and system of sampling fluids including an adsorbing chemical in a subterranean reservoir. One method may include modeling an interaction between the adsorbing chemical and a downhole tool, applying the model to a measurement of the adsorbing chemical, and adjusting the measurement in response to applying the model.

Abstract: A discharge ionization current detector of the present invention is used for a detector for a gas chromatograph and suitable for analyzing high-boiling components. A discharge ionization current detector 10 is mainly constituted by a plasma generating section 20 and an ion collecting section 30. Regarding the ion collecting section 30, an ion collecting electrode 31 and a bias electrode 32 are arranged, and furthermore, an insulating member made of sapphire or aluminum oxide having a purity equal to or greater than 99.5% is arranged between the ion collecting electrode 31 and the bias electrode 32.

Abstract: A test method and apparatus employs a microfluidic device to characterize properties of a fluid. The microfluidic device has an inlet port, an outlet port, and a microchannel as part of a fluid path between the inlet port and the outlet port. While a fluid is introduced into the microchannel, the fluid temperature is maintained while the fluid pressure in the microchannel is varied to characterize the properties of the fluid in the microchannel. The properties of the fluid can relate to a scale onset condition of the fluid at the pressure of the flow through the microchannel. In one aspect, fluid pressure in the microchannel is maintained while the fluid temperature is varied to characterize the properties of the fluid. In another aspect, flow rate of the fluid through the microchannel is varied while the fluid temperature is maintained to characterize the properties of the fluid in the microchannel.

Abstract: Disclosed herein are methods and systems for fluid characterization of fluid samples from a downhole fluid sampling tool. A fluid characterization method may include obtaining a fluid sample of a reservoir fluid; analyzing the fluid sample to derive input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample; determining component mole fractions of the fluid sample using a mole fraction distribution function; and determining calculated fluid properties using equation of state flash calculating.

Abstract: Conventional optical analysis tools containing an integrated computational element may have an operational profile that is too large for convenient use within confined locales. Optical analysis tools having a miniaturized operational profile can comprise: an electromagnetic radiation source that provides electromagnetic radiation to an optical train; and an optical computing device positioned within the optical train. The optical computing device comprises a planar array detector having at least two optical detection regions. At least one of the at least two optical detection regions has an integrated computational element disposed thereon. The planar array detector and the integrated computational element are in a fixed configuration with respect to one another.

Abstract: A sensor system that measures at least one parameter of water includes an electronics subsystem and includes a sensor housing electrically and mechanically coupled to the electronics subsystem. The sensor housing encloses a chamber that receives water via at least one inlet and that releases water via at least one outlet. At least one sensor has at least one electrode exposed to water in the chamber. A flow generator causes water to flow through the chamber. A plurality of objects within the chamber move in response to the water flow and abrasively clean the at least one electrode. Preferably, the sensor system includes a chlorine sensor having at least two electrodes. The electronics subsystem applies a first differential voltage between the two electrodes during a measurement interval and then applies a second differential voltage between the two electrodes during an interval following the measurement interval.

Abstract: The disclosed embodiments include a wellbore isolation device, a method to form the wellbore isolation device, and a downhole, device-tracking system. In one embodiment, the system includes a wellbore isolation device having a first identification tag and a dissolvable component. The first identification tag is operable to travel along a fluid flow path toward the surface of a well upon dissolution of the dissolvable component. The system also includes a detector disposed along the fluid flow path, where the detector is operable to detect the first identification tag when the first identification tag is proximate to the detector.

Abstract: A system to perform distributed acoustic sensing (DAS) in an environment with acoustic vibrations present includes at least an optical fiber positioned in said environment, wherein the optical fiber comprises N spatial channels and N laser pulses are launched into the N spatial channels of the optical fiber and propagate over a fiber length; and one or more sensors to measure N signals of acoustic vibration amplitude and frequency from each of N spatial channels, wherein the N signals are digitally added for spatial averaging and applied to determine DAS.

Abstract: A microcontroller-based system for measuring the impedance of a device under test (DUT), responsive to a square wave stimulus, includes parallel stimulus signal paths, selectable by a switch, that can correspond to different stimulus frequency ranges. At least one of the paths includes an off-chip PLL and integer divider circuit to modify the frequency of the stimulus. A discrete Fourier transform executed by a processor is used to determine the impedance of the DUT at the stimulus frequency. Multiple frequencies can be analyzed at the same time by using a summation circuit and/or by analyzing odd harmonics of the stimulus frequency.

Abstract: A magnetic flowmeter for measuring flow of a process fluid in a pipe includes a magnetic coil disposed adjacent to the pipe configured to apply a magnetic field to the process fluid. First and second electrodes are disposed within the pipe and electrically coupled to the process fluid and configured to sense an electromotive force (EMF) induced in the process fluid due to the applied magnetic field and flow of the process fluid. Input circuitry is coupled to the first and second electrodes and provides an output related to the sensed EMF. Diagnostic circuitry coupled to the input circuitry is configured to identify a saturation related condition and responsively provide a diagnostic output. In another embodiment, saturation prevention circuitry prevents saturation of the input circuitry.

Abstract: Various methods for detecting and accounting for the effects of half-stroking by a pump are provided. In one embodiment, a method includes operating a pump of a downhole tool to pump fluid from a formation through the downhole tool and determining pressure differentials between a formation pressure and pressure of the fluid within the downhole tool. The pressure differentials for each of a forward stroke and reverse stroke of the pump can be summed and then compared to enable identification of onset of half-stroking by the pump. Additional systems, devices, and methods are also disclosed.

Abstract: A gas analysis system and method filter different wavelengths of incident light using a variable light filter at different locations along a length of the variable light filter to form filtered light. The variable light filter is configured to be disposed between a light source generating plural different wavelengths of the incident light and a gas sample. Intensities of wavelengths of the filtered light are determined after the incident light generated by the light source passes through the variable light filter and the gas sample. The gas sample may be identified from among different potential gasses based on the intensity of the one or more wavelengths of the filtered light that is determined by the light detector.

Abstract: As system for measuring drilling fluid properties includes a capillary rheometer that is adapted to measure viscosity parameters of drilling fluid. The capillary rheometer includes a feed chamber, the feed chamber having a cavity, at least a first drain port for draining fluid out of the cavity, a double wall defining an annulus that opens to the cavity, and a feed port in an outer portion of the double wall that is in fluid communication with the annulus. The capillary rheometer also includes at least a first capillary tube coupled to at least the first drain port. Additionally, the disclosed system further includes a pump that is adapted to pump fluid to the feed port.

Abstract: A dynamic calibration system and method for measuring flow rates for individual petroleum wells in a well pad are provided. The dynamic calibration system and method include means for performing custom-calibration of said pressure sensor for each individual well to enhance the accuracy of the resulting flow rate measurements.

Abstract: A method of collecting samples that are not polluted at the outside of a borehole at a predetermined depth by using a multi-packer and an apparatus therefore. Contaminated water in the borehole between first and second packers of the multi-packer is selectively discharged into a contaminated water discharging vessel installed on a lower end of a sample collecting container by opening or closing an electronic switching valve in the contaminated water discharging vessel.

Abstract: Various disclosed distributed acoustic sensing (DAS) based systems and methods include embodiments that process the DAS measurements to detect one or more contrasts in acoustic signatures associated with one or more fluids flowing along a tubing string, and determine positions of the one or more contrasts as a function of time. The detected contrasts may be changes in acoustic signatures arising from one or more of: turbulence, frictional noise, acoustic attenuation, acoustic coupling, resonance frequency, resonance damping, and active noise generation by entrained materials. At least some of the contrasts correspond to interfaces between different fluids such as those that might be pumped during a cementing operation.

Abstract: The present disclosure provides for identification systems and related methods of use. The disclosed identification systems can include a first ink and a second ink, each of which can comprise one or more time-dependent properties. The first and second inks can be disposed in a spatial pattern on a substrate. A time-dependent property of the first ink and a time-dependent property of the second ink can cause a characteristic of the spatial pattern to change over time. For example, the spatial pattern can change from a first state at a first time to a second state at a second time. Evaluation and/or interpretation of the state of the spatial pattern at a second time can provide information about a product. Additionally, one or more of the first and second inks can include known time- and temperature-dependent properties that can be used to derive temperature related information.

Abstract: A system can include an interface to receive sensed data and economic data; a production control framework that includes a module for modeling motor efficiency of an electric submersible pump, a module for modeling gas composition of a fluid being pumped by an electric submersible pump, a module for modeling solid dynamics in a fluid being pumped by an electric submersible pump, a module to update one or more of the modules for modeling in response to receipt of data via the interface; and an interface to output control commands to a controller for an electric submersible pump based at least in part on data received by the interface and analyzed by the production control framework. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A fracture insert is disclosed including a first cylindrical portion and a second cylindrical portion disposed opposite the first cylindrical portion defining a radial gap therebetween to form an axial flow channel. The axial flow channel provides a flow path for a drilling fluid from a top of the cylindrical portions to a bottom of the cylindrical portions and the radial gap provides a flow path for the drilling fluid from the axial flow channel to a radial terminus of the first cylindrical portion and the second cylindrical portion.

Abstract: A fluid monitoring apparatus includes a housing and a tracer sensor attached to an exterior of the housing. The housing has at least one flow passage for a fluid sample and a port for the tracer sensor to monitor the fluid sample in the housing. In one example, the monitoring apparatus may include a plurality of tracer sensors attached to the housing, wherein the tracer sensors are interchangeably attached to the housing. In one embodiment, the monitoring apparatus may be attached to a first well for detecting the presence of a tracer in the first well, wherein the tracer is supplied from a second well.

Abstract: A system, method and computer-readable medium for monitoring a fluid injection at a downhole location in a wellbore is disclosed. A member is provided in the wellbore. The member includes a passage for flow of fluid and a fiber optic cable including a plurality of temperature sensitive sensors wrapped around the member. A selected temperature signal is imparted into the fluid flowing in the member. A temperature of the fluid exiting the member at the downhole location is measured using the plurality of temperature sensors. The measured temperature and the imparted temperature signal are compared to determine a flow parameter of the injected fluid.

Abstract: A method of determining characteristics of fluids flowed between a wellbore and multiple zones intersected by the wellbore can include measuring a first distributed temperature profile of the fluids along the wellbore while the fluids flow in one direction through the wellbore, and measuring a second distributed temperature profile of the fluids along the wellbore while the fluids flow in an opposite direction through the wellbore. Another method can include flowing the fluids in a first direction through an annulus formed between tubular strings in the wellbore, measuring a first distributed temperature profile of the fluids while flowing the fluids in the first direction, flowing the fluids in a second, opposite direction through the annulus, and measuring a second distributed temperature profile of the fluids along the wellbore while flowing the fluids flow in the second direction.

Abstract: Apparatus and method for monitoring flow meter operation. In one embodiment, a flow metering system includes a flow meter and a condition monitor. The flow meter is configured to measure volume of fluid flowing through the flow meter. The condition monitor is coupled to the flow meter and is configured to monitor a parameter of operation of the flow meter, and to compare a value of the parameter to a threshold. The condition monitor is also configured to generate an alarm based on the value exceeding the threshold, and to compute, based on the alarm, a confidence level indicating a degree of certainty that the system is operating in accordance with predetermined criteria.

Abstract: In or near real-time monitoring of fluids can take place using an opticoanalytical device that is configured for monitoring the fluid. Fluids can be monitored prior to or during their introduction into a subterranean formation using the opticoanalytical devices. Produced fluids from a subterranean formation can be monitored in a like manner. The methods can comprise providing at least one fracturing fluid component; combining the at least one fracturing fluid component with a base fluid to form a fracturing fluid; and monitoring a characteristic of the fracturing fluid using a first opticoanalytical device that is in optical communication with a flow pathway for transporting the fracturing fluid.

Abstract: A system is described for evaluating coagulation of particles in a downhole fluid-particle mixture based on dielectric measurements. An example downhole treatment is one in which flocs are used to plug a high-permeability subterranean formation zone as part of a stimulation procedure. An injection tube is positioned within the wellbore to the high-permeability zone. An instrumented section of tubing includes one or more dielectric probes that are positioned and configured to make dielectric measurements of the particle-fluid mixture flowing in the tubing or in the annulus. The downhole dielectric measurements are used to indicate whether or not the particle-fluid mixture has the desired structural properties. An operator on the surface can make adjustments in real-time according to the received dielectric measurements.

Abstract: A method for monitoring oscillation characteristics in a Coriolis, flow measuring device and to a correspondingly formed, Coriolis, flow measuring device in the case of which an excited oscillatory system is simulated with a digital model, which has at least one fittable parameter. The simulating includes, in such case, excitating the digital model in the same manner as the oscillatory system, calculating a simulation response variable of the simulated oscillations according to the digital model, and, performed over a plurality of signal modulations, iterative conforming of the at least one, fittable parameter in such a manner that the simulation response variable interatively approaches the response variable. Furthermore, it is ascertained whether a corresponding limit value is exceeded by the at least one, interatively ascertained parameter value for the at least one, fittable parameter or by at least one variable derived from the at least one, iteratively ascertained parameter value.

Abstract: This application describes methods and apparatus for monitoring flow at a given location downwell. The method of comprises performing fibre optic sensing on an optical fibre 204 deployed within the well 101. The optical fibre is attached to first tubing (201) that extends into the well to at least a first location (110a-c) at which it is wished to monitor inflow. The first tubing comprises at least one aperture (202a-c) having known properties at said first location. The first tubing is in fluid communication with flow tubing (107) that provides flow to/from the top (108) of the well. In use fluid therefore flows into the first tubing via the apertures (202a-c) which, having known properties, provide a calibrated response that can be detected by a fibre optic sensor unit (205).

Abstract: A sensor module for a sensing apparatus configured for operation downhole, within a borehole. The sensor module comprises a sensor array having a plurality of sensors to sense selected formation parameters and a control system for selective and independent operation of each sensor of the sensor array. Each sensor of the sensor array is configured or designed as a discrete sensor unit for individual and independent communication and control. Each sensor of the sensor array may have an associated electronics module that provides standardized electronic connectivity with the control system.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a tubing string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the tubing string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A tubing string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: 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.

Abstract: Advanced remote self-contained chromatographic systems and techniques for analyzing a mixture comprising components having a wide range of boiling points. The chromatographic systems and techniques can utilize components and techniques that allow staged, simultaneous, and/or sequential vaporization of an analyte to facilitate rapid analysis. The chromatographic systems and techniques can also utilize components and techniques that focus eluents from a first separation stage prior to reduce characterization time in subsequent stages.

Abstract: A technique provides a system and method utilizing a well system having a plurality of tools with actuatable components. The well system also comprises tracer elements which are unique with respect to corresponding tools of the well system. The tracer elements are positioned and oriented to open when physically engaged by the actuatable component of a corresponding tool. Released tracer material from the tracer element may be detected to confirm actuation of a specific tool in the well system.

Abstract: An apparatus for measuring phase behavior of a reservoir fluid comprises a first sample container and a second sample container in fluid communication with a microfluidic device defining a microchannel. A first pump and a second pump are operably associated with the sample containers and the microfluidic device to fill the microchannel with a reservoir fluid and to maintain a predetermined pressure of reservoir fluid within the microchannel.

Abstract: System and/or methods for removing noise from measurement data are disclosed. For example, pressure measurements may be used to identify a flow regime using the derivative of each of the pressure measurements. A time window may be defined about each pressure measurement and numerous or even all pressure measurements within the time window may be used to calculate the pressure derivative of each pressure measurement. A least-squares method or a least-absolute-deviations method may be used to compute a pressure-derivative curve. The iteratively-reweighted least-squares method may be used to solve least-absolute-deviation problems to compute a pressure-derivative curve with enhanced smoothing.

Abstract: A technique facilitates estimation of the viscosity of heavy oil. The method comprises evaluating a sample of oil by using an infrared spectrum sensor to obtain a reference temperature based on infrared absorbance. The reference temperature can then be used to determine viscosity data on the sample at a given temperature or temperatures.

Abstract: A wellhead test system comprising: i) a Coriolis mass flow meter configured to receive a flow of a liquid; ii) a water analyzer configured to receive the flow of the liquid; and iii) a controller coupled to the Coriolis mass flow meter and the water analyzer. The controller receives from the Coriolis mass flow meter at least one of: mass flow measurement data, mass density measurement data, and drive gain and also receives from the water analyzer at least one of water frequency measurement data, oil frequency measurement data, and insertion loss measurement data. The controller determines a gas volume fraction (GVF) value and modifies the operation of the Coriolis mass flow meter and the water analyzer based on the GVF value.