Abstract: An asymmetric fluidic oscillator can generate acoustic signals in a wellbore. The asymmetric fluidic oscillator can include an inlet housing defining an inlet channel, a feedback system, and an outlet housing defining an outlet channel. The inlet channel can be sized to receive fluid from the wellbore. The feedback system can be coupled to the inlet channel to oscillate the fluid from the wellbore. The outlet channel can be coupled to the feedback system and can be sized to receive the oscillated fluid from the feedback system. The outlet channel can include an asymmetric feature to generate acoustic signals detectable in the wellbore.

Abstract: A vehicle-mounted equipment and operation method for rapid detection of danger and hidden danger of a dike is provided, wherein the equipment includes: an operation vehicle; an operation shelter, located behind the cockpit of the operation vehicle and arranged on the chassis of the operation vehicle; a detection system, including a ground penetrating radar detection module, a transient electromagnetic detection module and a seismic wave detection module to perform physical detection of the dike.

Abstract: Techniques for monitoring a well clean-up process are disclosed. In one embodiment, a method includes routing a multiphase fluid having oil and water to a separator of a well testing apparatus, separating the multiphase fluid into separate fluids via the separator, and routing the separated fluids away from the separator. The method also includes measuring flow rates of oil and water leaving the separator and determining individual flow rates of oil and water entering the separator as part of the multiphase fluid based on the measured flow rates of oil and water leaving the separator. Additional systems, methods, and devices are also disclosed.

Abstract: An inflow indicator apparatus is for a well in an underground structure in which at least one tracer depot is arranged to be in contact with a partial fluid flow flowing from a producing structure into the well. The inflow indicator apparatus has a tubular body, a seal encircling a portion of the tubular body, arrangement of the at least one tracer depot externally on the tubular body, the seal being settable against an encircling wall, and the tubular body, the seal and the encircling wall defining an annulus forming a first flow path for the partial fluid flow which is separated from a second fluid flow path through the inflow indicator apparatus for a main fluid flow formed of a through fluid line in the tubular body, the first flow path extending from the seal to an end portion of the tubular body.

Abstract: A system for determining positions of a sand control service tool includes a wash pipe positioned below the sand control service tool. The system further includes a sensor attached to the wash pipe. The system also includes one or more magnets attached to downhole completion equipment. The sensor is configured to generate position indicator information that indicates whether the one or more magnets are within a threshold distance from the sensor. A crossover port of the sand control service tool is positioned above a sand control packer when the one or more magnets are within the threshold distance from the sensor.

Abstract: A well logging assembly adapted to collect data from the well, comprises a downhole locomotive to move a downhole portion of the logging assembly into the well, a power conduit to supply power from the surface to the downhole portion and a data conduit to transmit data from the downhole portion to the surface. The power conduit comprises a single electrical conductor to send electrical current to the downhole portion from a power supply at the surface. The downhole portion comprises an electrical contact exposed to the well for transmission of the return path for the electrical current to the surface.

Abstract: An exemplary time fault circuit interrupter for interrupting a power supply to an equipment unit upon the occurrence of a trip condition may include a sensor configured to monitor a current flow to the equipment unit. The circuit interrupter may also include a trip mechanism configured to interrupt the current flow. The circuit interrupter may further include a processor in communication with the sensor and the trip mechanism, and the processor may be configured to cause the trip mechanism to interrupt the current flow when a current flow time has reached a predetermined time limit.

Abstract: A method for measuring fluid flow including disposing a measurement device within a fluidic channel, the measurement device including a hydrodynamic central body, a plurality of arms coupled with and operable to extend from and retract to the hydrodynamic central body, and a plurality of sensors disposed within the hydrodynamic central body and distributed along the length of each of the plurality of arms; triggering, via an actuator, the plurality of arms to expand from the hydrodynamic central body until a portion of each of the plurality of arms abut a sidewall of the fluidic channel; collecting, via the plurality of sensors, measurements relating to one or more fluid flow parameters within the fluidic channel; triggering, via the actuator, the plurality of arms to contract inwards to the hydrodynamic central body; and retracting the measurement device from the fluidic channel.

Abstract: A sensing system that includes a cylindrical body including an internal flow channel that channels a first fluid therethrough, and a sampling chamber. The sampling chamber is in flow communication with an ambient environment. A venturi device is coupled within the cylindrical body, and the venturi device includes a high pressure portion and a low pressure portion. The low pressure portion is in flow communication with the sampling chamber. A valve is coupled within the cylindrical body and is positionable in at least a first position. A first flow channel is defined between the internal flow channel and the high pressure portion through the valve. The first flow channel channels the first fluid towards the high pressure portion such that the low pressure portion draws a second fluid into the sampling chamber from the ambient environment. A sensor assembly determines characteristics of the second fluid within the sampling chamber.

Abstract: Systems and methods for optimization of real time production operations. In one embodiment, a moving time horizon based parametric model provides fast predictions for production optimization in a short-term framework. In another embodiment, multiple technologies are selected in connection with asset performance workflows that are uniquely implemented in a multi-phase approach.

Abstract: A Holographic Multiphase Flowmeter permits reconstructing the type, size and distribution of Objects within a Multiphase Medium by analysis of the ultrasonic energy reflected from these Objects. If this Multiphase Medium is flowing through a pipe into which a preferred mode of ultrasonic energy is injected at a Reference location, and the amplitude of reflections from the current multiphase Objects at that location and the time it took after the last transmission for that reflected signal amplitude to arrive at the Receive transducer are recorded, it is possible to determine the velocity of the medium by measuring the travel time taken for these same Objects to arrive at a known distance downstream by correlating the same type of reflection data at this second Correlation location. Analysis of this data permits displaying type and size of the Objects in a graphic image showing their distribution within the liquid in real time.

Abstract: A method for measuring a well fluid parameter includes diverting a fluid through a first loop comprising one or more fluid parameter measurement components, determining a gross flow rate of the fluid, recirculating the fluid through a second loop upon determining the gross flow rate is below a threshold amount, and measuring the fluid parameter upon the gross flow rate reaching or exceeding the threshold amount.

Abstract: A method for operation of several adjacent magnetic-inductive flow meters, each of which has a measurement tube through which an electrically conductive medium flows, a magnetic field generating apparatus for permeating the medium with a magnetic field having a component perpendicular to the longitudinal axis of the measurement tube, and a measurement apparatus for measuring the voltage induced into the medium and for determining the flow rate from the induced voltage. Each flow meter has a control apparatus. In order to prevent variations of mutual influences on the flow rate measurements by the magnetic fields of adjacent flow meters, measured flow rate values from individual measurement processes and synchronous measurement processes are used to determine the mutual influences on the flow rate measurements, and influences that are free of variations are compensated by the magnetic fields of the adjacent flow meters being synchronized.

Abstract: A method for measuring a well fluid parameter includes diverting a fluid through a first loop comprising one or more fluid parameter measurement components, determining a gross flow rate of the fluid, recirculating the fluid through a second loop upon determining the gross flow rate is below a threshold amount, and measuring the fluid parameter upon the gross flow rate reaching or exceeding the threshold amount.

Abstract: A flow meter and method of determining a parameter of a downhole multiphase fluid is disclosed. Multiphase fluid flows through a downhole tubular member having first section, second section and third section, wherein the second section is disposed between the first section and the third section and an inner diameter of the second section is greater than an inner diameter of the first section and an inner diameter of the third section. Absolute pressure measurements of the multiphase fluid are obtained at each of the first section, second section and third section using absolute pressure gauges. The parameter of the downhole multiphase fluid is determined from the absolute pressure measurements.

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: Methods of manufacturing a fluid flow measuring device are provided. In an embodiment of the present invention, shields are disposed to prevent or reduce circulating electrical currents from causing a voltage difference that would adversely affect the measured voltage difference between two adjacent electrodes. Groups of sensors, e.g., two or more, may be placed within the shield. The shields may have any cross-section shape. A magnetic field source is disposed proximate the electrodes such that the magnetic field source is oriented to generate a magnetic field substantially orthogonal to an imaginary line intersecting each pair of electrodes. A voltage measuring circuit is electrically coupled to the plurality of electrodes and configured to measure a voltage difference between each pair of electrodes.

Abstract: A method of well testing to determine properties of oil and gas wells 8 comprises: applying oscillations to the flow rate and/or pressure at multiple wells 8 wherein the oscillations applied at different wells of the multiple wells are at different test frequencies; receiving measurements of flow rate in flows downstream of a production header that combines the flows from the multiple wells 8, and/or receiving measurements of pressure and/or temperature from individual wells 8; carrying out a frequency analysis of the pressure, flow rate and/or temperature measurements to determine pressure, flow rate and/or temperature variations induced by the applied oscillations; and determining properties of the different wells 8 of the multiple wells 8 based on the results of the frequency analysis at the test frequencies for the wells 8.

Abstract: An embodiment method for measuring fluid flow in a casing includes inserting a logging tool into the casing, wherein the logging tool having an internal axial flow channel and an electromagnetic flowmeter sensor disposed in the internal flow channel. The method also includes measuring an axial conductive fluid flow through the flow channel with the electromagnetic flowmeter sensor, while allowing bypass axial fluid flow to bypass the internal flow channel substantially unimpeded between an exterior of the logging tool and an interior wall of the casing.

Abstract: A method of testing an earth formation can include incrementally opening a choke while drilling into the formation is ceased, thereby reducing pressure in a wellbore, and detecting an influx into the wellbore due to the reducing pressure in the wellbore. Another method of testing an earth formation can include drilling into the formation, with an annulus between a drill string and a wellbore being pressure isolated from atmosphere, then incrementally opening a choke while drilling is ceased, thereby reducing pressure in the wellbore, detecting an influx into the wellbore due to the reducing pressure in the wellbore, and determining approximate formation pore pressure as pressure in the wellbore when the influx is detected. Drilling fluid may or may not flow through the drill string when the influx is detected. A downhole pressure sensor can be used to verify pressure in the wellbore.

Abstract: In a borehole logging tool, the flow of conductive fluid into or out of a wellbore at the wellbore wall is detected and measured with a sensor loop proximate the borehole inner wall. The sensor loop includes a series of contiguous sensors that act as electromagnetic flowmeters and provide fluid measurements covering the entire circumference of the sensor loop. The sensor loop includes an elastic element that forces the sensor loop outward to maintain pressure along the sensor loop circumference against the interior borehole wall. The sensor loop is designed to lie at a non-perpendicular angle to the wellbore axis, and mechanical arms press the top and bottom of the loop against the borehole inner wall.

Abstract: An apparatus for estimating a parameter of interest includes a conduit and a reactive media in the conduit. The reactive media interacts with a selected fluid component to control a flow parameter of the conduit. The apparatus also includes at least one sensor responsive to the flow parameter. The apparatus may be used for estimating a water content of a fluid flowing from a subterranean formation. The apparatus may include a flow path configured to convey fluid from the formation. The at least one sensor may be responsive to a pressure change in the flow path caused by interaction of the reactive media with water.

Abstract: A multiphase flow meter comprising two Venturis separated by a choke. The choke may be varied to adjust the properties of the multiphase fluid flow being measured. The two Venturis may be identical and may be arranged horizontally with respect to the multiphase fluid flow. The choke may be a choke in a return line of a managed pressure drilling system.

Abstract: A net oil and gas well test system for a set of oil and gas wells includes at least two net oil and gas measurement systems and a plurality of valves that are in fluid communication with the individual wells in the set and independently configurable between a first state, in which the valve routes flow to a first net oil and gas measurement system, and a second state, in which the valve routes flow to a second net oil and gas measurement system. Each net oil and gas measurement system suitably has the capability to measure a multiphase flow including oil, gas, and water without separation. For example, each measurement system can include a multiphase Coriolis meter and a water cut meter. Each measurement system suitably includes the capability to provide dynamic uncertainty estimates related to measurement of the multiphase flow.

Abstract: A method of modeling a subsurface hydrogeologic system within a study area can include applying an electric current directly to the subsurface hydrogeologic system and monitoring a magnetic field generated by the electric current in the subsurface hydrogeologic system. An electric current distribution can be identified within the study area by an inversion process based on the magnetic field. A model of the electric current distribution can be created.

Abstract: The apparatus for a borehole influx fluid parameters measurement comprises an enclosure open on two adjacent sides and having a poorly deformable heat-insulating rear wall, a cover and side walls made of elastically deformable heat-insulating material. Inside the enclosure a cellular structure of elastically deformable heat-insulating material is mounted with the gap relative to the enclosure's rear wall and having the through cells insulated from one another. Said cells forming the apparatus inlet openings on one side of the cellular structure and on the other side they are connected with the gap, the total area of the inlet openings significantly exceeds the area of the structure side surface they are located at. The transducers for the measurement of the influx fluid parameters are disposed inside the cells.

Abstract: A method of measuring multiphase flow of components in a wellbore fluid mixture by selectively heating components (e.g. oil and water) in the flow with electromagnetic energy, and detecting the heated components at a known distance downstream. The flow and velocity of components in the flow stream can be estimated with the present method. Example types of electromagnetic waves include infrared, microwaves, and radio waves. The different components can be heated simultaneously or at different times. The heated components can be detected with one or more temperature probes, and oil wet or water wet probes can be used to improve thermal contact to the corresponding components in the fluid stream.

Abstract: A flow meter and method of determining a parameter of a downhole multiphase fluid is disclosed. Multiphase fluid flows through a downhole tubular member having first section, second section and third section, wherein the second section is disposed between the first section and the third section and an inner diameter of the second section is greater than an inner diameter of the first section and an inner diameter of the third section. Absolute pressure measurements of the multiphase fluid are obtained at each of the first section, second section and third section using absolute pressure gauges. The parameter of the downhole multiphase fluid is determined from the absolute pressure measurements.

Abstract: Disclosed is a method for transient testing of an oil well to determine the individual, distinct skin factor components of an apparent skin factor, which includes opening the well to a first predefined choke setting to allow the reservoir fluid to flow through the well for a first predefined period of time, and measuring a production rate of the reservoir fluid through the well, when the first predefined period of time expires. The method further includes performing a shut-in of the well for a first predefined build-up period, and repeating, when the first predefined build-up period expires, the steps of the flowing, the measuring, and the performing for at least two additional choke settings. The distinct skin factor components of the apparent skin factor are determined using a graphical relationship between the determined apparent skin factors and the measured production rates.

Abstract: A technique facilitates flow monitoring in a well. A well component is designed for engagement with a well string deployed downhole into a wellbore. The well component has an internal flow passage through which well fluid is flowed. A sensor structure is mounted in the well component along the internal flow passage and comprises at least one sensor designed to sense a parameter related to fluid flow. The sensor structure is movable between a non-intrusive flow position with respect to the internal flow passage and a measurement position within the internal flow passage for measurement of the desired parameter.

Abstract: A measurement device is disclosed which includes a structure adapted to be removably coupled to a Christmas tree, a sleeve operatively coupled to the structure and a flowmeter positioned at least partially within the sleeve.

Abstract: Disclosed are a production logging tool and method for evaluating fluid produced from a formation of an oilfield. The fluid is measured by a water sensor to determine if the fluid is water, and a chloride sensor to determine chloride levels of the fluid. Based on the chloride levels of the fluid, it can be determined whether the fluid is naturally occurring water, or if the fluid is an injection fluid.

Abstract: A variable throat Venturi flow meter includes an upstream pipe section having an upstream cross-sectional area, a throat section having a variable throat cross-sectional area that is smaller than the upstream cross-sectional area, and a plurality of section-varying elements adapted to temporarily vary the throat cross-sectional area to allow a downhole tool to pass through the throat section.

Abstract: A passive liquid flow monitoring system includes a monitoring device made of a liquid-soluble material in which coded transponders are releasably retained. The monitoring device may be deployed proximate a region of interest in a hydrocarbon-producing well. Characteristics of a liquid flow in the region of interest may be determined based upon detection of transponders that are released from the monitoring device when the monitoring device is exposed to the liquid flow.

Abstract: An apparatus for metering fluid in a subterranean well includes an electric submersible pump having a motor, a seal section and a pump assembly and a metering assembly. The metering assembly includes an upper pipe section with an outer diameter, the upper pipe section having an upper pressure sensing means, and a lower pipe section with an outer diameter smaller than the outer diameter of the upper pipe section, the lower pipe section having a lower pressure sensing means. A power cable is in electronic communication with the electric submersible pump and with the metering assembly.

Abstract: An apparatus for production logging includes a conveyance device configured to traverse a wellbore, a multicapacitance flow meter positioned on the conveyance device and configured to estimate at least one parameter relating to holdup; and a spinner flow meter positioned on the conveyance device and configured to estimate at least one parameter relating to a flow velocity of at least one fluid phase.

Abstract: A well testing system and method are provided. The well testing system includes a separator-exchanger module that may include a modular frame, a separator and/or a modular steam-heat exchanger. A surge tank module can include a surge tank, frames, and two surge tanks. A manifold model can include a compact manifold. The various modules of the well testing system can be interconnected using various guiding, stopping, and/or fixing clamps.

Abstract: Methods and apparatuses for detecting radial flows of conductive fluid are provided. In an embodiment of the present invention, shields are used to prevent or reduce circulating electrical currents from causing a voltage difference that would adversely affect the measured voltage difference between two adjacent electrodes. The shields may be a conduit through which conductive fluid may flow. Groups of sensors, e.g., two or more, may be placed within the shield. The shields may have any cross-section shape. Generally, once the circulating electrical current flow between the electrode pairs is substantially reduced or eliminated, only the voltage difference from the localized induced electric field remains. This way, a true induced voltage may be measured, and thus an accurate value for the fluid velocity may be determined.

Abstract: In a borehole logging tool, the flow of conductive fluid into or out of a wellbore at the wellbore wall is detected and measured with a sensor loop proximate the borehole inner wall. The sensor loop includes a series of contiguous sensors that act as electromagnetic flowmeters and provide fluid measurements covering the entire circumference of the sensor loop. The sensor loop includes an elastic element that forces the sensor loop outward to maintain pressure along the sensor loop circumference against the interior borehole wall. The sensor loop is designed to lie at a non-perpendicular angle to the wellbore axis, and mechanical arms press the top and bottom of the loop against the borehole inner wall.

Abstract: An apparatus and method of measuring a parameter characteristic of a rock formation in an oil well is provided with a device for generating a sensing field within a volume of the rock formation and a device for causing a flow through the volume in the presence of the sensing field, further including sensors responsive to changes in the volume, wherein a sensor response is indicative of the amounts of fluid, particularly hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements can be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Abstract: Fluid flow measurement device and method. In one embodiment, a tool comprises a rotating arm with a sensor pad to measure fluid flow into or out of the casing wall. The arm maintains the sensor pad in close proximity to the casing inner wall. The tool diameter is variable to allow the tool to traverse variable diameter casings and pass obstacles. The sensor pad comprises flow channels to direct the flow of fluid by electromagnetic sensors configured to detect conductive fluid flow.

Abstract: In a borehole logging tool, the flow of conductive fluid into or out of a wellbore at the wellbore wall is detected and measured with a sensor loop proximate the borehole inner wall. The sensor loop includes a series of contiguous sensors that act as electromagnetic flowmeters and provide fluid measurements covering the entire circumference of the sensor loop. The sensor loop includes an elastic element that forces the sensor loop outward to maintain pressure along the sensor loop circumference against the interior borehole wall. The sensor loop is designed to lie at a non-perpendicular angle to the wellbore axis, and mechanical arms press the top and bottom of the loop against the borehole inner wall.

Abstract: A flow meter for measuring the velocity of surrounding fluid, comprising a rotatable member rotatably coupled to a shaft member, wherein the shaft member comprises a measuring electrical circuit comprising an AC power supply and a primary coil, the rotatable member comprising a passive non-permanent magnet marker responsive to a magnetic field, the arrangement being such that when the circuit is powered by the AC supply the coil generates a magnetic field and the marker is positioned on the rotatable member such that rotation of the rotatable member in response to fluid drag on the member causes the distance between the marker and the coil to oscillate, the marker interacting with the magnetic field at its closest approach to the coil, thereby to cause a measurable electrical response in the circuit.

Abstract: Flowmeters and methods of measuring a fluid flow or manufacturing flowmeters are presented. A flowmeter has a tool body and one or more spinner arms configured to extend with a first end away from the tool body and a second end joined to the tool body, when deployed to measure a fluid flow. Each spinner arm includes a helical blade configured to rotate due to a fluid flowing substantially parallel to a longitudinal axis of the tool body, around a rotation axis between the first end and the second end.

Abstract: A method and apparatus for determining a fluid level and/or output flow during operation of a centrifugal pump, are provided, which may be used for production of gas and/or oil from a well, and include a vector feedback model to derive values of torque and speed from signals indicative of instantaneous current and voltage drawn by the pump motor, a pump model which derives values of the fluid flow rate and the head pressure for the pump from torque and speed inputs, a pumping system model that derives, from the estimated values of the pump operating parameters, an estimated value of fluid level and other pumping system parameters. Controllers responsive to the estimated values of the pumping system parameters control the pump to maintain fluid level at the pump input, near an optimum level, or within a safe operating range and/or output flow from the pump.

Abstract: A technique facilitates flow monitoring in a well. A well component is designed for engagement with a well string deployed downhole into a wellbore. The well component has an internal flow passage through which well fluid is flowed. A sensor structure is mounted in the well component along the internal flow passage and comprises at least one sensor designed to sense a parameter related to fluid flow. The sensor structure is movable between a non-intrusive flow position with respect to the internal flow passage and a measurement position within the internal flow passage for measurement of the desired parameter.

Abstract: A fluid flow metering device comprises a ball valve locatable in a fluid flow, having at least two transverse bores through the ball valve, a first transverse bore and a second transverse bore. The first transverse bore includes a fluid flow metering apparatus for measuring the rate of fluid flow through the first transverse bore. The ball valve is preferably rotatable between a first metering position where fluid is flowable through the first transverse bore and a second open position where fluid is flowable through the second transverse bore. In addition, the second transverse bore is dimensioned so that a tool is movable through the second transverse bore when the ball valve is in the second open position.

Abstract: A measurement device is disclosed which includes a structure adapted to be removably coupled to a Christmas tree, a sleeve operatively coupled to the structure and a flowmeter positioned at least partially within the sleeve.

Abstract: A bi-directional fluid flow sensor is disclosed. The sensor comprises a turbine configured to rotate along an axis as a result of fluid flowing past the turbine substantially in the direction of the axis; a magnet mounted to the turbine and configured to rotate with the turbine; and a magnetic flux angle sensor provided adjacent to the turbine and configured to detect the relative flux angle of the magnet as it rotates. The bi-directional fluid flow sensor is sensitive and robust and may be used in a downhole well for example.

Abstract: Processes and systems for logging production of fluid produced into a well bore without intervention of the well are disclosed. Two or more markers may be introduced into produced fluid at spaced apart locations along a well. The time for each marker to reach a common point may be measured and production rates for produced fluids at each spaced apart location may be calculated.