FR3105403A1 - Débitmètre doppler radar à micro-ondes pour puits d'hydrocarbures - Google Patents
Débitmètre doppler radar à micro-ondes pour puits d'hydrocarbures Download PDFInfo
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N22/00—Investigating or analysing materials by the use of microwaves or radio waves, i.e. electromagnetic waves with a wavelength of one millimetre or more
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
- E21B47/107—Locating fluid leaks, intrusions or movements using acoustic means
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
- G01F1/663—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters by measuring Doppler frequency shift
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F15/00—Details of, or accessories for, apparatus of groups G01F1/00 - G01F13/00 insofar as such details or appliances are not adapted to particular types of such apparatus
- G01F15/06—Indicating or recording devices
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- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
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- G01F15/063—Indicating or recording devices for remote indication using electrical means
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Abstract
DÉBITMÈTRE DOPPLER RADAR À MICRO-ONDES POUR PUITS D'HYDROCARBURES. Un débitmètre (10) destiné à être utilisé dans un puits d'hydrocarbure (2) pour mesurer une vitesse de fluide et/ou une direction de fluide d'un fluide polyphasique en mouvement (MF) présent dans le puits d'hydrocarbure (2). Le débitmètre comprend un module frontal micro-ondes (11) comprenant au moins une antenne émettrice (16Tx) et au moins une antenne réceptrice (16Rx) et un circuit micro-ondes (17). L’antenne émettrice (16Tx) transmet des signaux électromagnétiques vers le fluide polyphasique (MF) à une fréquence élevée allant de 10 à 100 GHz. Le débitmètre comprend un module électronique analogique convertissant un signal Doppler analogique (21, 24) successivement en un signal Doppler analogique amplifié (26) et un signal Doppler numérique (28). Le débitmètre comprend un module de traitement numérique (13) comprenant un algorithme de transformée de Fourier rapide (29) pour traiter le signal Doppler numérique (28) en un spectre en fréquences Doppler (30) et un filtre (31) fournissant un spectre en fréquences Doppler compressé (32). Le spectre Doppler contient des informations indicatives de la vitesse de fluide et/ou de la direction de fluide du fluide polyphasique en mouvement (MF). Une coque de protection (15) comprend une première partie (15A) positionnée au-dessus desdites antennes (16Rx, 16Tx) et transparente aux signaux électromagnétiques, et une seconde partie (15B) opaque aux signaux électromagnétiques. Figure pour l’abrégé: Figure 1
Description
TECHNICAL FIELD.
The invention relates to a downhole flowmeter intended for use in a hydrocarbon well. The invention is particularly applicable to the measurement of velocity and direction of flow in a hydrocarbon producing well, in particular to identify and determine flow profile of various phases (oil, gas and water). The invention is particularly applicable in harsh downhole environment including high temperature (up to 200°C), high pressure (up to 2.000bars) and corrosive fluid.
BACKGROUND.
After the drilling, the evaluation, and the completion of a hydrocarbon well, production operations are implemented. During production, various parameters related to the drilled earth formations and the different phases (e.g. oil, gas and water) of multiphase fluid mixtures flowing into the borehole of the hydrocarbon well from the hydrocarbon bearing zones are measured and monitored. Various measurement logs (production logging) are performed in order to evaluate and optimize the production of the hydrocarbon well. As examples, these measurements may be related to the flow contributions of the different perforated zones, the identification of fluid types and properties, such as water, oil and gas relative proportions (holdups), etc... The measurement logs may be used to decide on corrective actions such as the shut-in of zones responsible for unwanted water or sand production, or the perforation of additional zones of interest for increasing oil and/or gas production, or the stimulation of zones that are producing below expectation.
Downhole tools are commonly deployed in the borehole of the hydrocarbon well for performing measurements and/or interventions. The downhole tools are run down inside the well-bore from the top of the hydrocarbon well, the wellhead, down to the bottom of the hydrocarbon well. The downhole tools typically comprise various sensors acquiring data such as pressure, temperature, fluid density, fluid velocity, fluid conductivity along portions of the well-bore. The downhole tools are suspended by a line or cable which may also be used to communicate real time data to surface equipment. Current hydrocarbon wells often comprise a vertical well section, deviated well sections and horizontal well sections. In highly deviated or horizontal wells, the tool weight will not provide sufficient force to travel down, thus coiled tubing, rods or tractors are used to push the tools along the well-bore.
A known technique to evaluate flow is a flowmeter using single or multiple spinners. The relationship between spinner propeller rotation frequency (often referred as RPS, rotation per second) and flow speed is complex and depends on many factors including fluid density, fluid viscosity, propeller design, rotation axis damping, bearing, etc... A limitation of such a conventional solution is that it is not adapted and accurate enough to identify and determine flow profile of various phases (oil, gas and water) in vertical, deviated or horizontal hydrocarbon well along length ranging from a few meters to a few kilometers.
Another known technique is a flowmeter using ultrasound. For example, the document WO2016145524 describes a device and method for imaging, measuring and identifying multiphase fluid flow in wellbores using phased array Doppler ultrasound. The device includes a radiaIly configured or ring-shaped ultrasound transducer that when deployed in a well in Doppler mode can measure the velocity of radially flowing fluids in the wellbore and generate a 3D image of radial flow in the wellbore, including flowback into the wellbore after fracturing operations, or flow leaving the wellbore during water injection operations. The ring-shaped ultrasound transducer can also simultaneously operate in B-mode to generate a B-mode image of the wellbore liner upon which the Doppler image can be overlaid. The device may also include a forward-facing ultrasound transducer either instead of or in place of the ring-shaped transducer for obtaining information and images on axial flow in the wellbore in Doppler mode, and the location of phase boundaries and phase locations in B-mode. The drawback of such a solution is that it is limited to measure flow of liquid and, thus, it is not adapted to measure flow of gas or mixture of liquid and gas.
SUMMARY OF THE DISCLOSURE.
It is an object of the invention to propose a downhole flowmeter intended for use in a hydrocarbon well using micro-wave radar doppler principle that overcomes one or more of the limitations or drawbacks of the existing downhole flowmeter. It is another object of the invention to propose a downhole flowmeter that can measure radial flow in hydrocarbon wells.
According to one aspect, there is provided a flowmeter intended for use in a hydrocarbon well for measuring a fluid velocity and/or a fluid direction of a moving multiphase fluid present in the hydrocarbon well, including:
- a micro-wave front end module comprising at least one emitting antenna and at least one receiving antenna and a micro-wave circuit, the micro-wave circuit comprising an oscillator coupled to the emitting antenna for causing said antenna to transmit electromagnetic signals towards the multiphase fluid at a high frequency ranging from 10 to 100 GHz, a mixer coupled to the receiving antenna and to a filter for generating an analog doppler signal depending on echo electromagnetic signals from moving multiphase fluid;
- an analog electronics module comprising an amplifier and an analog-to-digital converter converting the analog doppler signal successively into an amplified analog doppler signal and a digital doppler signal;
- a digital processing module comprising a Fast Fourier Transform algorithm for processing the digital doppler signal into a Doppler frequency spectrum and a filter providing a compressed Doppler frequency spectrum, said Doppler spectrum containing information indicative of the fluid velocity and/or the fluid direction of the moving multiphase fluid; and
- a protective shell protecting the micro-wave front end module, the analog electronics module and the digital processing module from multiphase fluid, the protective shell comprising a first part positioned over said antennas and being transparent to electromagnetic signals, and a second part being opaque to electromagnetic signals.
- a micro-wave front end module comprising at least one emitting antenna and at least one receiving antenna and a micro-wave circuit, the micro-wave circuit comprising an oscillator coupled to the emitting antenna for causing said antenna to transmit electromagnetic signals towards the multiphase fluid at a high frequency ranging from 10 to 100 GHz, a mixer coupled to the receiving antenna and to a filter for generating an analog doppler signal depending on echo electromagnetic signals from moving multiphase fluid;
- an analog electronics module comprising an amplifier and an analog-to-digital converter converting the analog doppler signal successively into an amplified analog doppler signal and a digital doppler signal;
- a digital processing module comprising a Fast Fourier Transform algorithm for processing the digital doppler signal into a Doppler frequency spectrum and a filter providing a compressed Doppler frequency spectrum, said Doppler spectrum containing information indicative of the fluid velocity and/or the fluid direction of the moving multiphase fluid; and
- a protective shell protecting the micro-wave front end module, the analog electronics module and the digital processing module from multiphase fluid, the protective shell comprising a first part positioned over said antennas and being transparent to electromagnetic signals, and a second part being opaque to electromagnetic signals.
The emitting antenna and receiving antenna may be extending perpendicular to a longitudinal axis of the flowmeter at a front part of the flowmeter so as to form an axial micro-wave radar doppler sensor being sensitive to the multiphase fluid having an axial velocity and flowing along a longitudinal axis of the hydrocarbon well.
The emitting antenna and receiving antenna may be extending parallel to a longitudinal axis of the flowmeter at a periphery of the flowmeter so as to form a radial micro-wave radar doppler sensor being sensitive to the multiphase fluid having a radial velocity and corresponding to lateral entries into the hydrocarbon well.
The flowmeter may comprise three, four or eight radial micro-wave radar doppler sensors forming a triangle, a square or an octagon, angularly distributed in a cross-section plane perpendicular to the longitudinal axis of the flowmeter, respectively.
The emitting antenna and receiving antenna may be phased array patch antennas.
The emitting antenna, the receiving antenna and the micro-wave circuit may be integrated on a same printed circuit board PCB, said antennas and said micro-wave circuit being either on the same side of said PCB, or on opposite sides of said PCB.
The flowmeter may further comprise a quadrature mixer and a second filter so as to provide an analog in-phase doppler signal and an analog quadrature doppler signal for determining the fluid direction of the moving multiphase fluid.
The digital processing module may be further coupled to a telemetry module used to communicate with surface equipment or a memory used to record measurements downhole.
The filter may be a logarithmic filter.
The first part of protective shell may be a protection cap having a conical shape, or a protection cap having a half spherical shape, and/or a protection hollow cylinder extending longitudinally.
The first part may be made of PolyEther Ether Ketone PEEK material, and the second part may be made of stainless steel.
The flowmeter may comprise a radar module part, a power and processing module part and a rear connection part coupled together in series, having a cylindrical shape and extending longitudinally along the longitudinal axis of the flowmeter, the radar module part comprising at least one micro-wave front end module.
The power and processing module part may comprise a battery support cradle receiving a battery, and at least one PCB including the analog electronics module and the digital processing module.
The rear connection part may comprise a first rear connector used to connect one side of the flowmeter with a sub section of a downhole tool, a second rear connector coupling the rear connection part to the power and processing module part, and an electrical coaxial connector connected to the PCB of the analog electronics and digital processing modules.
The flowmeter may further comprise a front connection part including a first front connector used to connect one side of the flowmeter with another sub section of a downhole tool, and a second front connector coupling the front connection part to the radar module part.
According to another aspect, there is provided a downhole tool used to measure and analyze a fluid present in a hydrocarbon well, the tool being adapted for displacement along and within the hydrocarbon well and comprising a micro-wave radar doppler flowmeter in accordance with the invention.
According to a further aspect, there is provided a method for measuring radial and/or axial flow of a fluid mixture present in a hydrocarbon well according to multiple cross-sections of the hydrocarbon well the method comprising running a flowmeter according to the invention along a defined distance within the hydrocarbon well, transmitting electromagnetic signals towards the multiphase fluid at a high frequency ranging from 10 to 100 GHz, receiving echo electromagnetic signals from moving multiphase fluid, and processing said echo electromagnetic signals such as to provide a flow profile image of the hydrocarbon well.
The micro-wave radar doppler flowmeter of the invention has the following advantages:
- No in-situ calibration is necessary; the sensor response is modelized by well-known physics and is based on constants known to a high degree of accuracy such as speed of light;
- It allows a direct and extremely accurate measurement of velocity of “flowing structures” traveling within the flow along the axis of the wellbore;
- The flowmeter has no moving part achieving robust hardware;
- Sensor and electronics with embedded software enables a robust extraction of velocity;
- The sensor has a small size and can be integrated in a small outer diameter flowmeter achieving minimal perturbation of the flow from tool structure, and owing to such small size, the tool may comprise a plurality of sensors angularly distributed around its longitudinal axis;
- The flowmeter structure is simple, compact achieving low cost and being maintenance free;
- The flowmeter is self-calibrating, leading to significant savings compared to spinner calibration time in “shut-in condition”; and
- It is possible to directly measure radial flow from perforations (cased hole) or fractures clusters (open hole, slotted liners or sand screens).
- No in-situ calibration is necessary; the sensor response is modelized by well-known physics and is based on constants known to a high degree of accuracy such as speed of light;
- It allows a direct and extremely accurate measurement of velocity of “flowing structures” traveling within the flow along the axis of the wellbore;
- The flowmeter has no moving part achieving robust hardware;
- Sensor and electronics with embedded software enables a robust extraction of velocity;
- The sensor has a small size and can be integrated in a small outer diameter flowmeter achieving minimal perturbation of the flow from tool structure, and owing to such small size, the tool may comprise a plurality of sensors angularly distributed around its longitudinal axis;
- The flowmeter structure is simple, compact achieving low cost and being maintenance free;
- The flowmeter is self-calibrating, leading to significant savings compared to spinner calibration time in “shut-in condition”; and
- It is possible to directly measure radial flow from perforations (cased hole) or fractures clusters (open hole, slotted liners or sand screens).
Other advantages will become apparent from the hereinafter description of the invention.
BRIEF DESCRIPTION OF THE DRAWINGS.
The present invention is illustrated by way of examples and not limited to the accompanying drawings, in which like references indicate similar elements:
FIG. 1 is a cross-section view illustrating a downhole tool of the invention being deployed in a horizontal section of a hydrocarbon well;
FIGS. 2-6 are schematic and simplified views illustrating an exemplary embodiment of the micro-wave radar doppler flowmeter of the invention, associated electronics and operation principles;
FIGS. 7-9 are schematic views illustrating various antenna embodiments of the micro-wave radar doppler flowmeter of the invention;
FIGS. 10-13 are a A-A cross-section view, a partially transparent side view, a B-B cross-section view, and a perspective view of a first embodiment of the micro-wave radar doppler flowmeter of the invention comprising a single axial micro-wave radar doppler sensor;
FIGS. 14-16 are a A-A cross-section view, a side view and a B-B cross-section view of a second embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising three radial micro-wave radar doppler sensors;
FIGS. 17-19 are a A-A cross-section view, a partially exploded side view and a B-B cross-section view of a third embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising four radial micro-wave radar doppler sensors;
FIGS. 20-22 and 25 are a A-A cross-section view, a side view, a B-B cross-section view and a partially exploded perspective view of a fourth embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising eight radial micro-wave radar doppler sensors;
FIGS. 23, 24 and 26 are a A-A cross-section view, a side view and a perspective view illustrating any one of the radar modules according to the second, third and fourth embodiments assembled with inferior and superior parts and forming the micro-wave radar doppler flowmeter of the invention;
FIGS. 27-30 are a C-C cross-section view, a A-A cross-section view, a bottom view and a B-B cross-section view of a fifth embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising one axial and four radial micro-wave radar doppler sensors; and
FIGS. 31-34 are perspective views illustrating the radar module, the head of the radar module, and central part of the radar module according to different viewing angles of the fifth embodiment.
FIG. 1 is a cross-section view illustrating a downhole tool of the invention being deployed in a horizontal section of a hydrocarbon well;
FIGS. 2-6 are schematic and simplified views illustrating an exemplary embodiment of the micro-wave radar doppler flowmeter of the invention, associated electronics and operation principles;
FIGS. 7-9 are schematic views illustrating various antenna embodiments of the micro-wave radar doppler flowmeter of the invention;
FIGS. 10-13 are a A-A cross-section view, a partially transparent side view, a B-B cross-section view, and a perspective view of a first embodiment of the micro-wave radar doppler flowmeter of the invention comprising a single axial micro-wave radar doppler sensor;
FIGS. 14-16 are a A-A cross-section view, a side view and a B-B cross-section view of a second embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising three radial micro-wave radar doppler sensors;
FIGS. 17-19 are a A-A cross-section view, a partially exploded side view and a B-B cross-section view of a third embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising four radial micro-wave radar doppler sensors;
FIGS. 20-22 and 25 are a A-A cross-section view, a side view, a B-B cross-section view and a partially exploded perspective view of a fourth embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising eight radial micro-wave radar doppler sensors;
FIGS. 23, 24 and 26 are a A-A cross-section view, a side view and a perspective view illustrating any one of the radar modules according to the second, third and fourth embodiments assembled with inferior and superior parts and forming the micro-wave radar doppler flowmeter of the invention;
FIGS. 27-30 are a C-C cross-section view, a A-A cross-section view, a bottom view and a B-B cross-section view of a fifth embodiment of a radar module of the micro-wave radar doppler flowmeter of the invention comprising one axial and four radial micro-wave radar doppler sensors; and
FIGS. 31-34 are perspective views illustrating the radar module, the head of the radar module, and central part of the radar module according to different viewing angles of the fifth embodiment.
Description détaillée
DETAILED DESCRIPTION.
The invention will be understood from the following description, in which reference is made to the accompanying drawings.
FIG. 1 illustrates a downhole tool, for example a production logging tool 1 being deployed into a wellbore of a hydrocarbon well 2 that has been drilled into an earth subterranean formation 3. In this particular example, the downhole tool is deployed in a horizontal section of a hydrocarbon well that has been further fractured at defined locations (i.e. fracture clusters FC1, FC2, FC3). The production logging tool 1 is used to analyze at least one property of a multiphase flow mixture MF flowing in the hydrocarbon well 2. The multiphase flow mixture MF is characterized by holdup, slippage velocity and phase segregation. Holdup is the percentage by volume of the gas, oil and/or water content in the wellbore measured over a cross-sectional area (based on the wellbore inner diameter). Slippage velocity is the relative velocity existing between light phases and heavy phase (light phases move faster than heavier phases). Phase segregation is the tendency of fluids to stratify into different layers because of differences in density between oil, water and gas and due to the immiscibility of water and oil, and the limited miscibility (depending on temperature and pressure) of gas in oil and water. The wellbore refers to the drilled hole or borehole, including the open hole or uncased portion of the well. The borehole refers to the inside diameter of the wellbore wall, the rock face that bounds the drilled hole. The open hole refers to the uncased portion of a well. While most completions are cased, some are open, especially in horizontal wells where it may not be possible to cement casings efficiently. The production logging tool 1 is suitable to be deployed and run in the wellbore of the hydrocarbon well 2 for performing various analysis of the multiphase flow mixture MF properties irrespective of a cased or uncased nature of the hydrocarbon well. The production logging tool 1 may comprise various sub sections 4 having different functionalities and may be coupled to surface equipment through a wireline 5 (or alternative equipment such as coiled tubing) which is operable at a surface equipment to displace the tool along the well. At least one sub section 4 comprises a measuring device generating measurements logs, namely measurements versus depth or time, or both, of one or more physical quantities in or around the well 2. Wireline logs are taken downhole, transmitted through the wireline 5 to surface and recorded there, or else recorded downhole and retrieved later when the instrument is brought to surface. There are numerous log measurements (e.g. electrical properties including conductivity at various frequencies, sonic properties, active and passive nuclear measurements, dimensional measurements of the wellbore, formation fluid sampling, formation pressure measurement, etc…) possible while the production logging tool 1 is displaced along and within the hydrocarbon well 2 drilled into the subterranean formation 3. Surface equipment is not shown and not described in details herein. In the following the wall of the wellbore irrespective of its cased (cement or pipe) or uncased nature is referred to wall 6. Various fluid (that may include solid particles) entries F1, F2, F3 may occur from the subterranean formation 3 towards the wellbore 2. Once in the wellbore 2, these fluid entries form the multiphase flow mixture MF that generally flows towards the surface. In particular, in deviated or horizontal wells, the multiphase fluid mixture MF may be segregated. In a particular example, the segregated multiphase flow mixture MF may flow as a layer of gas above a layer of oil, further above a layer of immiscible oil and water mixture from top to bottom (i.e. in the direction of earth gravity).
The production logging tool 1 has an elongated cylindrical body shape and comprises a central pressure-resistant rigid housing 7 carrying at least one centralizer arrangement 8. The production logging tool 1 extends longitudinally about the longitudinal axis YY'. The centralizer arrangement 8 substantially centers the production logging tool 1 with respect to the wellbore axis XX' during operations in the wellbore. In this way, the longitudinal axis YY' of the production logging tool 1 and the wellbore axis XX' are substantially parallel, generally co-axial. Further, when the production logging tool 1 is moved along the wellbore, the centralizer arrangement 8 is adapted to fit through borehole sections of different diameter while offering a minimal frictional resistance.
The downhole tool 1 further comprises a micro-wave radar doppler flowmeter 10 of the invention so as to determine the individual production contribution from the fracture clusters FC1, FC2, FC3, and also the global flow in the wellbore. In particular, the micro-wave radar doppler flowmeter 10 is used to measure both radial flow F1, F2, F3 and longitudinal/axial flow MF in the wellbore.
The micro-wave radar doppler flowmeter 10 of the invention is based on an electromagnetic EM micro-wave radar technology. The frequency of the electromagnetic waves generated by the micro-wave radar doppler flowmeter is in the range of 10 to 100 GHz. The micro-wave radar doppler flowmeter can operate in oil and gas producing wells under extreme conditions (high temperature up to 200°C, high pressure up to 2.000bars and corrosive fluid). Such extreme conditions yield a number of challenges in terms of robustness, accuracy, self-calibration, small dimensions compatible with well inner diameter that have not been addressed until now.
The basic operation of the micro-wave radar doppler flowmeter is based on a dual antenna structure composed of an emitting antenna fed by a radio frequency oscillator and a receiving antenna. Signals generated by the receiving antenna are mixed in the mixer in order to produce a low frequency doppler signal which is then amplified, digitalized and processed.
FIG. 2 is a simplified schematic view of the micro-wave radar doppler flowmeter 10 in an exemplary embodiment. The micro-wave radar doppler flowmeter 10 comprises a micro-wave front end module 11, an analog electronics module 12, a digital processing module 13, a telemetry module 14 and a protective shell 15. The micro-wave front end module 11 is coupled to the analog electronics module 12 that is further coupled to the digital processing module 13. The digital processing module 13 is coupled to the telemetry module 14. The micro-wave front end module 11 comprises emitting and receiving antennas 16Tx, 16Rx coupled to a micro-wave circuit 17. The telemetry module 14 is used to communicate CTS with surface equipment. The telemetry module 14 is optional and may be replaced by a memory when all measurements are recorded downhole. The protective shell 15 protects the micro-wave front end module 11, the analog electronics module 12, the digital processing module 13 and the telemetry module 14 from the external environment encountered in the hydrocarbon well. The protective shell 15 comprises a first part 15A that is transparent to electromagnetic wave, and a second part 15B that is opaque to electromagnetic wave.
Micro-wave front end:
FIGS. 3 and 4 are simplified schematic views of two alternate micro-wave front end modules 11. FIG. 4 differs from FIG. 3 in that the micro-wave front end modules 11 further comprises a mixer that is a quadrature mixer. A quadrature mixer enables determining the flow direction. This is advantageous as recirculation can occur in deviated wellbore where non-miscible phases can flow (e.g. oil and water). In an ideal context where a laminar flow occurs, the signal at the output of the mixer is a perfect sinus and the doppler spectrum is a single peak. In real well conditions, the doppler spectrum is much more complex and requires specific filtering in order to be able to extract flow velocity value. Indeed, beyond the flow itself several effects induce a doppler shift on signal, namely:
During logging, the waves reflections from the wellbore wall may induce a doppler signal which is related to the flowmeter being run (at a logging speed) in the wellbore uphole (towards the surface) or downhole (towards the bottom of the well). This means that, in order to discriminate the flow signal from the flowmeter speed signal, the logging speed must be inferior to the expected fluid velocities to be measured. This is an acceptable condition for most operations as typical logging speeds are from 0,1 to 0,3 m/s and velocity from fluid flow ranges from 0,5 to 10 m/s. For very low velocity measurements the flowmeter must be deployed in stationary mode.
The spectrum extracted from the received micro-wave comes from contributions from a multitude of bubbles reflectors which have different velocities. The Doppler spectrum comprises multiple peaks. Indeed, in many flow conditions the flow is turbulent and vortices are present in the wellbore. In contradistinction, in a laminar flow, all the bubbles have substantially the same speed, and a Doppler spectrum comprises a single peak.
The micro-wave front end module 11 comprises emitting and receiving antennas 16Tx, 16Rx coupled to the micro-wave circuit 17. The micro-wave circuit 17 comprises an oscillator 18, a mixer 19 and a filter 20. The micro-wave circuit 17 of FIG. 3 provides an analog in-phase doppler signal 21. The micro-wave circuit 17 of FIG. 4 further comprises a quadrature mixer 22 and a second filter 23. The micro-wave circuit 17 of FIG. 4 provides an analog in-phase doppler signal 21 and an analog quadrature doppler signal 24.
The micro-wave circuit may comprise High Electron Mobility Transistors (HEMT) based on III-V semiconductor heterostructures. Such a technology achieves low noise values and high gain up to frequencies above 50 GHz that is well adapted to design radar oscillator. The antennas 16Tx, 16Rx will be described in details hereinafter in relation with FIGS. 7 to 9.
Signal and data processing:
FIG. 5 is a simplified schematic view of the data processing chain, namely the operation of the analog electronics module 12 and the digital processing module 13. The analog electronics module 12 comprises an amplifier (A) 25 and an analog-to-digital converter (A/D) 27. It converts the analog in-phase doppler signal 21 (resp. the analog quadrature doppler signal 24) into an amplified analog doppler signal 26 and then a digital doppler signal 28.
The digital processing module 13 is a processing arrangement that includes a microcontroller with assembler coded embedded firmware. Data management during production logging operation must be handled carefully due to data size limitations. Measurements may be either recorded in the flowmeter itself for post job analysis or transmitted in real time to surface equipment. Though, in both cases, the amount of data that can be acquired by the flowmeter is limited. In situ downhole computation is thus required as recording or transmission of the full doppler signal waveform for further processing is not possible. The processing arrangement aims at implementing an efficient data treatment and data compression. As an example, the digital processing module 13 comprises a Fast Fourier Transform (FFT) 29, a logarithmic filter (LOG) 31 and a communication module (COM) 33.
Firstly, a Fast Fourier Transform (FFT) algorithm is performed downhole onto the full digital doppler signal 28. The Fast Fourier Transform 29 provides a Doppler spectrum 30.
Secondly, a downhole data processing algorithm is performed downhole onto the Doppler spectrum 30. This algorithm takes into account the fact that the signal amplitude can vary in high proportion depending on the flow conditions. As an example, a water slug moving towards the antenna in a gas filled wellbore will produce large echoes compared to another situation where small oil bubbles are moving in a brine filled wellbore (i.e. the water continuous medium is highly attenuating the micro-wave beam). An appropriate data processing algorithm enables operating the flowmeter in all, at least in most, cases of flow conditions. The downhole data processing algorithm may be based on a logarithmic filter 31. Such a filter enables covering all, at least most, ranges of flow conditions with sufficient resolution while optimizing said data size. The logarithmic filter 31 provides a compressed Doppler spectrum 32.
Thirdly, the compressed Doppler spectrum 32 is further processed by the communication module 33 as data signal 34 to be either transmitted to surface via the telemetry module 14 (transmitted data) or recorded in memory (not shown) downhole (recorded data).
The processed spectra (data signal 34) resulting from the hereinbefore process may be analyzed using a computation algorithm running on a computer at the surface. FIG. 6 illustrates compressed Doppler spectrum 32 as downhole data (DD) 40 (function of time t), processed Doppler spectrum 41 after surface computation (SC) and flow speed FS-RAD and FS-AXI calculation 42 (function of depth d) after surface computation (SC) based on radial RAD and axial AXI measurements. Spectra analysis is either performed in real time on the transmitted data or as a post processing step on the recorded data. This algorithm filters the line speed signal (namely the velocity of the tool supporting the flowmeter imposed by the line or coil tubing) and amplitude fronts detection (namely the velocity of flow speed relative to the tool supporting the flowmeter). It allows extracting the flow speed signal from other signals such as those generated by echoes from the borehole wall and turbulences effects.
The doppler theory gives the equation which governs the reflected micro-wave frequency shift from target echoes moving towards the antenna:
[math 1]
(1)
with:
Fd: doppler frequency (Hz);
Ft: micro-wave transmitting frequency or operating frequency (typically > 10 GHz);
v: velocity of structures moving in the wellbore along its axis (m/s);
c: light speed in medium (around 3.108m/s);
: angle between flow velocity vector and transmitted micro-wave beam (This angle is known, either the fluid is flowing towards the antenna and angle is nil, or the antenna is a phased array antenna or an inclined antenna and angle is defined by the corresponding antenna configuration with respect to the flow direction).
[math 1]
with:
Fd: doppler frequency (Hz);
Ft: micro-wave transmitting frequency or operating frequency (typically > 10 GHz);
v: velocity of structures moving in the wellbore along its axis (m/s);
c: light speed in medium (around 3.108m/s);
The micro-wave radar doppler flowmeter may operate in a continuous way, i.e. micro-wave radar beams are emitted and received continuously. In one configuration, the micro-wave radar doppler flowmeter comprises two distinct emitting and receiving antennas 16Tx, 16 Rx. A first antenna is the emitting antenna 16Tx that is excited by an emission signal provided by the oscillator 18 such as to radiate an electromagnetic wave. A second antenna is the receiving antenna 16Rx that detects echo electromagnetic waves from moving targets such as to generate a reception signal. Both emission and reception signals are mixed with the mixer 19 (or 19 and 22) in order to extract the doppler signal 21 (or 21 and 24) at low frequency.
For a 30 GHz operating frequency it gives a doppler shift of 200 Hz/(m/s). As an example, it means that water droplets traveling at 10 m/s in a gas stream flowing towards the flowmeter will give a doppler frequency of 2KHz. Amplitude of signal depends on the number and size of water droplets, information which can also be useful to understand well characteristics, such as water entries in a gas producing well.
There are several advantages in operating the radar at high frequency, namely in range from 10 to 100 GHz. Firstly, targets having small dimensions (ranging from 3 mm to 3 cm) can be detected because the electromagnetic energy reflected from such targets is dependent on its relative size to the wavelength of the electromagnetic wave. Secondly, measuring low flow velocity at high logging speed (for operation efficiency) requires to minimize acquisition time for Fast Fourier Transform FFT computation and therefore to operate at higher minimum doppler frequency (resolving low frequency signal requires an acquisition times equal to the period of the signal). Following the doppler equation (1) for a fixed velocity, the doppler frequency is proportional to the transmission frequency.
Antenna:
Various embodiments of antenna 16Tx, 16Rx are illustrated as top view in FIGS. 7-9 as simplified layout. A patch antenna is simple to manufacture using Printed Circuit Board (PCB) technology. Each antenna, being either an emission antenna 16Tx or a reception antenna 16Rx, is manufactured according to a microstrip patch design on a PCB 50A, 50B, 50C. It is made of rectangular conductive structures 51A, 51B, 51C separated from a ground plane by a thin layer of dielectric material. Alternatively, the micro-wave circuit, more precisely the micro-wave front end circuitry 17 can be integrated on the same PCB (broken line extension) or on the back (not shown) of the same PCB using metal micro via 52. Thus, the need for connectors is reduced and the whole assembly including patch antenna and associated micro-wave circuit can be assembled into a package of small dimensions. Typically, dimensions of 25x25x3 mm can be achieved for a complete “24 GHz front end” including antenna and circuit.
By multiplying the number of emission antennas and reception antennas on the same PCB, the micro-wave beam can be steered.
FIG. 7 illustrates a patch antenna 50A in a configuration where two emission antennas 16Tx are parallel to two reception antennas 16Rx.
FIG. 8 illustrates a phased array patch antenna 50B for angled beam emission in a configuration where eight emission antennas 16Tx are parallel to eight reception antennas 16Rx.
FIG. 9 illustrates a phased array patch antenna 50C for angled beam emission in a configuration where eight emission antennas 16Tx are in series with eight reception antennas 16Rx. Such a configuration enables achieving minimal PCB width.
The micro-wave beam can be steered with a controlled angle using such phased array patch antennas. Such an antenna design is advantageous because the velocity profiles are measured around a flowmeter included in a tubular/cylindrical tool structure as will be explained hereinafter. Multiple antennas may be positioned around the periphery of the flowmeter, each antenna being sensitive to an angular section of the wellbore. This is advantageous in deviated wells where segregations occur. It enables measuring a flow profile around the flowmeter. Further, the implementation of PCB having a low width enables integrating a large number of antennas in the flowmeter.
FIGS. 10-34 show various embodiments of the micro-wave radar doppler flowmeter 10. The micro-wave radar doppler flowmeter 10 comprises a front connection part 60, a radar module part 61, a power and processing module part 62 and a rear connection part 63. In particular, FIGS. 10, 11, 13, 23, 24 and 26 show a complete micro-wave radar doppler flowmeter 10 while the other FIGS. only show the front connection part 60 and the radar module part 61 of the micro-wave radar doppler flowmeter 10 embodiments. The front connection part 60, the radar module part 61, the power and processing module part 62 and the rear connection part 63 are coupled together in series and have a general cylindrical shape and extend longitudinally along the longitudinal axis YY’.
The front connection part 60 comprises a first front connector 70 at a distal end. Such a first front connector 70 may be a threaded connector used to connect one side of the micro-wave radar doppler flowmeter with other sub section 4 of the downhole production tool 1 (visible in FIG. 1). The front connection part 60 further comprises a second front connector 71 that couples the front connection part 60 to the radar module part 61. Such a second front connector 71 may be a threaded connector and further includes a sealing 72, for example at least one O-ring, advantageously multiple O-rings.
The radar module part 61 comprises at least one micro-wave front end module 11, each micro-wave front end module 11 comprising emitting and receiving antennas 16Tx, 16Rx (not visible except on FIG. 25) and the micro-wave circuit 17 (not visible on FIGS. 10-34). The micro-wave front end module 11 is covered by a protective shell 64 ensuring a protection with respect to external fluids (high pressure, high temperature and corrosive). The protective shell 64 allows transmission of the micro-wave beam in both directions, namely emission micro-wave from the antenna towards the fluid, and reflected micro-wave from the liquid towards the antenna. The protective shell 64 may be made of high strength polymer material such as PolyEther Ether Ketone PEEK (organic thermoplastic polymer in the polyaryletherketone family) or a ceramic material. The protective shell 64 may take various shape, for example a protection cap 64A having a conical shape as seen in FIGS. 10 and 11 (first embodiment), or a protection hollow cylinder 64B extending longitudinally as seen in FIGS. 14-16 (second embodiment), FIGS. 17-19 (third embodiment), FIGS. 20-22 (third embodiment), FIGS. 23-25 (fourth embodiment), or a combination of a protection hollow cylinder 64B extending longitudinally and a protection cap 64C having a half spherical shape as seen in FIGS. 27-32 (fifth embodiment).
The power and processing module part 62 comprises a battery support cradle 80 receiving a battery 81, and at least one PCB 82 including the analog electronics module 12 and the digital processing module 13. The PCB 82 of the analog electronics and digital processing modules may be positioned between the power and processing module part 62 and the rear connection part 63 (as depicted in FIGS. 20, 21, 23, 27, 28 and 31), or between the power and processing module part 62 and the radar module part 61 (as depicted in FIGS. 10 and 11). The power and processing module part 62 further comprises a protective casing 83 (only visible in FIGS. 23, 24 and 26) that is sealed against the radar module part 61 and the rear connection part 63 by means of appropriate sealing, for example O-rings (not shown).
The rear connection part 63 comprises a first rear connector 90 at a distal end. Such a first rear connector 90 may be a threaded connector used to connect one side of the micro-wave radar doppler flowmeter with other sub section 4 of the downhole production tool 1 (visible in FIG. 1). The rear connection part 63 further comprises a second rear connector 91 that couples the rear connection part 60 to the power and processing module part 62. Such a second rear connector 71 may be a threaded connector. The rear connection part 63 further includes an electrical coaxial connector 92 that is sealed against the internal wall of the first rear connector 90 by means of a sealing 93, for example an O-ring. The electrical coaxial connector 92 is connected to the PCB 82 of the analog electronics and digital processing modules.
A hollow passageway 95, for example positioned along the longitudinal axis YY’ is provided for driving electric wire from the various PCBs (from and towards the radar module part and the power and processing module part).
FIGS. 10-13 show a first embodiment of a micro-wave radar doppler flowmeter comprising a single micro-wave radar doppler sensor 65A positioned axially with respect to the longitudinal axis YY’. The single micro-wave radar doppler sensor 65A is received in a recess 76 at an end portion of the radar module part 61 that connects with the front connection part 60 and covered by the protection cap 64A. In this embodiment, the single micro-wave radar doppler sensor 65A is a PCB including the micro-wave front end module 11 that comprises antennas 16Tx, 16Rx and the micro-wave circuit 17. FIG. 10 is a A-A cross-section view of the first embodiment. FIG. 11 is a partially transparent side view of the first embodiment. FIG. 12 is a B-B cross-section view of the first embodiment. FIG. 13 is a perspective view of the first embodiment. The axial micro-wave radar doppler sensor 65A comprises anyone of the patch antenna and micro-wave circuit of the various PCB alternative embodiments 50A, 50B, 50C previously described in relation with FIGS. 7-9.
The front connection part 60 of the first embodiment further comprises longitudinal lateral holes 73 opening towards an open chamber 74 into which protrudes a radar protection cap 64A of conical shape. The radar protection cap 64A is further sealed against the second connector 71 by means of sealing 75, for example at least one O-ring, advantageously multiple O-rings.
FIGS. 14-16 show a second embodiment of a micro-wave radar doppler flowmeter comprising three radial micro-wave radar doppler sensor 65B, 65C and 65D extending parallelly to the longitudinal axis YY’. FIG. 14 is a A-A cross-section view of the second embodiment. FIG. 15 is a side view of the second embodiment. FIG. 16 is a B-B cross-section view of the second embodiment.
FIGS. 17-19 show a third embodiment of a micro-wave radar doppler flowmeter comprising four radial micro-wave radar doppler sensors 65B, 65C, 65D and 65E extending parallelly to the longitudinal axis YY’. FIG. 17 is a A-A cross-section view of the third embodiment. FIG. 18 is a partially exploded side view of the third embodiment. FIG. 19 is a B-B cross-section view of the third embodiment.
FIGS. 20-22 and 25 show a fourth embodiment of a micro-wave radar doppler flowmeter comprising eight radial micro-wave radar doppler sensors 65B, 65C, 65D, 65E, 65F, 65G, 65H and 65I extending parallelly to the longitudinal axis YY’. FIG. 20 is a A-A cross-section view of the fourth embodiment. FIG. 21 is a side view of the fourth embodiment. FIG. 22 is a B-B cross-section view of the fourth embodiment. FIG. 25 is a partially exploded perspective view of the fourth embodiment.
In these three embodiments, the radar module part 61 has a front portion 84, a middle portion 85 and rear portion 86. The front portion 84 has a reduced diameter and is received in the first front connector 70 of the front connection part 60. Each radial micro-wave radar doppler sensor 65B, 65C and 65D is received in a recess 87 of the middle portion 85 of the radar module part 61 such that:
the three radial micro-wave radar doppler sensor 65B, 65C and 65D are forming a triangle in the B-B cross-section view as depicted in FIG. 16;
the four radial micro-wave radar doppler sensor 65B, 65C, 65D and 65E are forming a square in the B-B cross-section view as depicted in FIG. 19; and
the eight radial micro-wave radar doppler sensor 65B, 65C, 65D, 65E, 65F, 65G, 65H and 65I are forming an octagon in the B-B cross-section view as depicted in FIG. 22.
The protection hollow cylinder 64B is blocked in place between the front connection part 60 and a shoulder 88 defined by the rear portion 86. The middle portion 85 also includes sealings 89 at each end between the middle portion 89 and the protection hollow cylinder 64B, for example at least one O-ring, advantageously multiple O-rings at each end.
In these three embodiments, each radial micro-wave radar doppler sensor 65B, 65C, 65D, 65E, 65F, 65G, 65H and 65I is a PCB including the micro-wave front end module 11 that comprises antennas 16Tx, 16Rx and the micro-wave circuit 17. Each radial micro-wave radar doppler sensor 65B, 65C, 65D, 65E, 65F, 65G, 65H and 65I comprises anyone of the patch antenna and micro-wave circuit of the various PCB embodiments 50A, 50B, 50C previously described in relation with FIGS. 7-9.
FIGS. 23, 24 and 26 are a A-A cross-section view, a side view and a perspective view, respectively, illustrating any one of the radar module part 61 according to the second, third and fourth embodiments assembled with the power and processing module part 62, the front connection part 60 and the rear connection part 63 such as to form the micro-wave radar doppler flowmeter 10.
FIGS. 27-34 show a fifth embodiment of a micro-wave radar doppler flowmeter incorporating a combination of one axial micro-wave radar doppler sensor 65A positioned axially with respect to the longitudinal axis YY’, and four radial micro-wave radar doppler sensors 65B, 65C, 65D and 65E extending parallelly to the longitudinal axis YY’. FIG. 27 is a C-C cross-section view of the fifth embodiment. FIG. 28 is a A-A cross-section view of the fifth embodiment. FIG. 29 is a bottom view of the fifth embodiment. FIG. 30 is a B-B cross-section view of the fifth embodiment. FIGS. 31-34 are perspective views illustrating the radar module part 61 (FIG. 31), the head of the radar module (FIG. 32), and the central part of the radar module (FIGS. 33 and 34) according to different viewing angles of the fifth embodiment without any protective shell (protection hollow cylinder 64B) for sake of clarity, respectively.
With respect to the axial micro-wave radar doppler sensor 65A, the fifth embodiment differs from the first embodiment in that:
the axial micro-wave radar doppler sensor 65A is supported by the front connection part 60 (and not by the radar module part 61 as in the other embodiments), and
the front connection part 60 does not include a front connector, instead a front protection cap 64C having a half spherical shape is positioned at the distal end of the front connection part 60.
Thus, this embodiment is intended for being positioned at the end of the production logging tool. The axial micro-wave radar doppler sensor 65A is able to cover the forward direction D (see FIG. 32).
The four radial micro-wave radar doppler sensors 65B, 65C, 65D and 65E extends parallelly to the longitudinal axis YY’. Said sensors are supported in recesses along the middle portion 85 such that they are perpendicular two by two in order to emit and receive micro-waves towards perpendicular directions D1, D1’ vs. D2, D2’ (see FIG. 33) and towards opposite side of the radar module part D1, D2 vs D1’, D2’ (all the directions being perpendicular to the longitudinal axis YY’).
Thus, with the fifth embodiment, the micro-wave radar doppler flowmeter is able to cover all the directions around in the wellbore because it comprises axially and radially configured micro-wave radar doppler sensors 65A, 65B, 65C, 65D and 65E that emits electromagnetic waves forward (i.e. parallel to the longitudinal axis of the wellbore XX’) from the single axial sensor 65A towards the wellbore axis (see arrow direction D), and radially outwards (i.e. perpendicular to the longitudinal axis of the wellbore XX’) from the radial sensors 65B, 65C, 65D and 65E towards the wall of the wellbore (see arrows directions D1, D1’, D2, D2’). By running the micro-wave radar doppler flowmeter in the wellbore uphole (towards the surface) or downhole (towards the bottom of the well) along a defined distance, the micro-wave radar doppler flowmeter provides measurements of multiple cross-sections of the wellbore all along the wellbore, thus providing a flow profile image.
The drawings and their description hereinbefore illustrate rather than limit the invention. It should be appreciated that embodiments of the present invention are adapted to wells having any deviation with respect to the vertical. In the oilfield industry, in particular during production operations, all the embodiments of the present invention are equally applicable to cased and uncased borehole (open hole), and also other kind of downhole conduits where a fluid may flow. Further, the fluid may be flowing or at rest/static in the conduit. Furthermore, the device includes multiple micro-wave radar doppler sensor oriented in different directions. On the one hand, the present invention is not limited to the particular embodiments showing a single, three, four, five or eight micro-wave radar doppler sensors as any other number of sensors may be appropriate for specific measurement applications. On the other hand, the present invention is not limited to the particular embodiments showing a sensor extending axially and longitudinally with respect to the longitudinal axis YY’ as the sensor may also be inclined with respect to the longitudinal axis YY’. Furthermore, despite the fact that the flowmeter is depicted as positioned at an end of the production logging tool in FIG. 1, it may also be positioned in-between two sub-sections of the production logging tool.
Claims (17)
- A flowmeter (10) intended for use in a hydrocarbon well (2) for measuring a fluid velocity and/or a fluid direction of a moving multiphase fluid (MF) present in the hydrocarbon well (2), including:
- a micro-wave front end module (11) comprising at least one emitting antenna (16Tx) and at least one receiving antenna (16Rx) and a micro-wave circuit (17), the micro-wave circuit (17) comprising an oscillator (18) coupled to the emitting antenna (16Tx) for causing said antenna to transmit electromagnetic signals towards the multiphase fluid (MF) at a high frequency ranging from 10 to 100 GHz, a mixer (19) coupled to the receiving antenna (16Rx) and to a filter (20) for generating an analog doppler signal (21, 24) depending on echo electromagnetic signals from moving multiphase fluid (MF);
- an analog electronics module (12) comprising an amplifier (25) and an analog-to-digital converter (27) converting the analog doppler signal (21, 24) successively into an amplified analog doppler signal (26) and a digital doppler signal (28);
- a digital processing module (13) comprising a Fast Fourier Transform (29) algorithm for processing the digital doppler signal (28) into a Doppler frequency spectrum (30) and a filter (31) providing a compressed Doppler frequency spectrum (32), said Doppler spectrum containing information indicative of the fluid velocity and/or the fluid direction of the moving multiphase fluid (MF); and
- a protective shell (15) protecting the micro-wave front end module (11), the analog electronics module (12) and the digital processing module (13) from multiphase fluid (MF), the protective shell (15) comprising a first part (15A) positioned over said antennas (16Rx, 16Tx) and being transparent to electromagnetic signals, and a second part (15B) being opaque to electromagnetic signals. - The flowmeter of claim 1, wherein the emitting antenna (16Tx) and receiving antenna (16Rx) are extending perpendicular to a longitudinal axis (YY’) of the flowmeter at a front part of the flowmeter so as to form an axial micro-wave radar doppler sensor (65A) being sensitive to the multiphase fluid (MF) having an axial velocity and flowing along a longitudinal axis (XX’) of the hydrocarbon well (2).
- The flowmeter of claim 1 or claim 2, wherein the emitting antenna (16Tx) and receiving antenna (16Rx) are extending parallel to a longitudinal axis (YY’) of the flowmeter at a periphery of the flowmeter so as to form a radial micro-wave radar doppler sensor (65A) being sensitive to the multiphase fluid (MF) having a radial velocity and corresponding to lateral entries into the hydrocarbon well (2).
- The flowmeter of claim 3, wherein the flowmeter comprises three, four or eight radial micro-wave radar doppler sensors (65B, 65C, 65D, 65E, 65F, 65G, 65H, 65I) forming a triangle, a square or an octagon, angularly distributed in a cross-section plane perpendicular to the longitudinal axis (YY’) of the flowmeter, respectively.
- The flowmeter according to anyone of claims 1 to 4, wherein the emitting antenna (16Tx) and receiving antenna (16Rx) are phased array patch antennas.
- The flowmeter according to anyone of claims 1 to 5, wherein the emitting antenna (16Tx), the receiving antenna (16Rx) and the micro-wave circuit (17) are integrated on a same printed circuit board PCB (50A, 50B, 50 C), said antennas (16Tx, 16 Rx) and said micro-wave circuit (17) being either on the same side of said PCB, or on opposite sides of said PCB.
- The flowmeter according to anyone of claims 1 to 6, further comprising a quadrature mixer (22) and a second filter (23) so as to provide an analog in-phase doppler signal (21) and an analog quadrature doppler signal (24) for determining the fluid direction of the moving multiphase fluid (MF).
- The flowmeter according to anyone of claims 1 to 7, wherein the digital processing module (13) is further coupled to a telemetry module (14) used to communicate with surface equipment or a memory used to record measurements downhole.
- The flowmeter according to anyone of claims 1 to 8, wherein the filter (31) is a logarithmic filter.
- The flowmeter according to anyone of claims 1 to 9, wherein the first part (15A) of protective shell (64) is a protection cap (64A) having a conical shape, or a protection cap (64C) having a half spherical shape, and/or a protection hollow cylinder (64B) extending longitudinally.
- The flowmeter according to anyone of claims 1 to 10, wherein the first part (15A) is made of PolyEther Ether Ketone (PEEK) material, and the second part (15B) is made of stainless steel.
- The flowmeter according to anyone of claims 1 to 11, comprising a radar module part (61), a power and processing module part (62) and a rear connection part (63) coupled together in series, having a cylindrical shape and extending longitudinally along the longitudinal axis of the flowmeter (YY’), the radar module part (61) comprising at least one micro-wave front end module (11).
- The flowmeter of claim 12, wherein the power and processing module part (62) comprises a battery support cradle (80) receiving a battery (81), and at least one PCB (82) including the analog electronics module (12) and the digital processing module (13).
- The flowmeter according to anyone of claims 12 to 13, wherein the rear connection part (63) comprises a first rear connector (90) used to connect one side of the flowmeter with a sub section (4) of a downhole tool (1), a second rear connector (91) coupling the rear connection part (60) to the power and processing module part (62), and an electrical coaxial connector (92) connected to the PCB (82) of the analog electronics and digital processing modules (12, 13).
- The flowmeter according to anyone of claims 12 to 14, further comprising a front connection part (60) including a first front connector (70) used to connect one side of the flowmeter with another sub section (4) of a downhole tool (1), and a second front connector (71) coupling the front connection part (60) to the radar module part (61).
- A downhole tool (1) used to measure and analyze a multiphase fluid (MF) present in a hydrocarbon well (2), the tool (1) being adapted for displacement along and within the hydrocarbon well (2) comprising a flowmeter (10) in accordance with anyone of claims 1 to 15.
- A method for measuring radial and/or axial flow of a fluid mixture (MF) present in a hydrocarbon well (2) according to multiple cross-sections of the hydrocarbon well (2), the method comprising running a flowmeter (10) in accordance with anyone of claims 1 to 15 along a defined distance within the hydrocarbon well (2), transmitting electromagnetic signals towards the multiphase fluid (MF) at a high frequency ranging from 10 to 100 GHz, receiving echo electromagnetic signals from moving multiphase fluid (MF), and processing said echo electromagnetic signals such as to provide a flow profile image of the hydrocarbon well (2).
Priority Applications (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR1914973A FR3105403B1 (fr) | 2019-12-19 | 2019-12-19 | Débitmètre doppler radar à micro-ondes pour puits d'hydrocarbures |
| GB2019192.0A GB2594545B (en) | 2019-12-19 | 2020-12-04 | Microwave doppler flowmeter for hydrocarbon wells |
| US17/127,725 US11656187B2 (en) | 2019-12-19 | 2020-12-18 | Microwave doppler flowmeter for hydrocarbon wells |
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR1914973 | 2019-12-19 | ||
| FR1914973A FR3105403B1 (fr) | 2019-12-19 | 2019-12-19 | Débitmètre doppler radar à micro-ondes pour puits d'hydrocarbures |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| FR3105403A1 true FR3105403A1 (fr) | 2021-06-25 |
| FR3105403B1 FR3105403B1 (fr) | 2021-11-19 |
Family
ID=70456884
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| FR1914973A Active FR3105403B1 (fr) | 2019-12-19 | 2019-12-19 | Débitmètre doppler radar à micro-ondes pour puits d'hydrocarbures |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US11656187B2 (fr) |
| FR (1) | FR3105403B1 (fr) |
| GB (1) | GB2594545B (fr) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20230186218A1 (en) * | 2021-12-13 | 2023-06-15 | Saudi Arabian Oil Company | Early warning detection of performance deviation in well and reservoir surveillance operations |
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| US4452077A (en) * | 1982-07-19 | 1984-06-05 | Atlantic Richfield Company | Borehole ultrasonic flow meter |
| GB2251526A (en) * | 1984-05-18 | 1992-07-08 | Thomson Csf | Processor for separating coherent signals from noise in doppler radar |
| FR2722293A1 (fr) * | 1994-07-08 | 1996-01-12 | Inst Francais Du Petrole | Debitmetre polyphasique |
| FR2722292A1 (fr) * | 1994-07-08 | 1996-01-12 | Inst Francais Du Petrole | Debitmetre polyphasique |
| US20090107252A1 (en) * | 2006-11-02 | 2009-04-30 | Ohm Electric Co., Ltd. | Flow measurement device |
| EP2587227A1 (fr) * | 2011-10-31 | 2013-05-01 | Welltec A/S | Outil d'extraction pour déterminer la vitesse de débit |
| US20160146743A1 (en) * | 2013-07-01 | 2016-05-26 | M-Flow Technologies Ltd | Fluid sensor |
| WO2016145524A1 (fr) | 2015-03-16 | 2016-09-22 | Darkvision Technologies Inc. | Dispositif et procédé pour imager un écoulement dans des puits de pétrole et de gaz à l'aide d'ultrasons doppler de réseau à commande de phase |
| US20170016316A1 (en) * | 2015-07-13 | 2017-01-19 | Openfield | Downhole acoustic transducer, downhole probe and tool comprising such a transducer |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2205668B1 (fr) * | 1972-11-07 | 1981-04-10 | Thomson Csf | |
| US6049762A (en) * | 1997-12-18 | 2000-04-11 | Perkin Elmer Llc | Standardizing a spectrometric instrument |
| US6606571B2 (en) * | 2001-10-12 | 2003-08-12 | Deere & Company | Microwave flow sensor for a harvester |
| US10401203B2 (en) * | 2015-12-09 | 2019-09-03 | Baker Hughes Incorporated | Multi-frequency micro induction and electrode arrays combination for use with a downhole tool |
-
2019
- 2019-12-19 FR FR1914973A patent/FR3105403B1/fr active Active
-
2020
- 2020-12-04 GB GB2019192.0A patent/GB2594545B/en active Active
- 2020-12-18 US US17/127,725 patent/US11656187B2/en active Active
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4452077A (en) * | 1982-07-19 | 1984-06-05 | Atlantic Richfield Company | Borehole ultrasonic flow meter |
| GB2251526A (en) * | 1984-05-18 | 1992-07-08 | Thomson Csf | Processor for separating coherent signals from noise in doppler radar |
| FR2722293A1 (fr) * | 1994-07-08 | 1996-01-12 | Inst Francais Du Petrole | Debitmetre polyphasique |
| FR2722292A1 (fr) * | 1994-07-08 | 1996-01-12 | Inst Francais Du Petrole | Debitmetre polyphasique |
| US20090107252A1 (en) * | 2006-11-02 | 2009-04-30 | Ohm Electric Co., Ltd. | Flow measurement device |
| EP2587227A1 (fr) * | 2011-10-31 | 2013-05-01 | Welltec A/S | Outil d'extraction pour déterminer la vitesse de débit |
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| WO2016145524A1 (fr) | 2015-03-16 | 2016-09-22 | Darkvision Technologies Inc. | Dispositif et procédé pour imager un écoulement dans des puits de pétrole et de gaz à l'aide d'ultrasons doppler de réseau à commande de phase |
| US20170016316A1 (en) * | 2015-07-13 | 2017-01-19 | Openfield | Downhole acoustic transducer, downhole probe and tool comprising such a transducer |
Also Published As
| Publication number | Publication date |
|---|---|
| GB2594545A (en) | 2021-11-03 |
| GB202019192D0 (en) | 2021-01-20 |
| US20210190558A1 (en) | 2021-06-24 |
| US11656187B2 (en) | 2023-05-23 |
| FR3105403B1 (fr) | 2021-11-19 |
| GB2594545B (en) | 2022-05-04 |
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