CN110700811B - Waveguide phase measurement method and device for water content and flow of oil well - Google Patents
Waveguide phase measurement method and device for water content and flow of oil well Download PDFInfo
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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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
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- 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
- G01F1/56—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 using electric or magnetic effects
- G01F1/58—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 using electric or magnetic effects by electromagnetic flowmeters
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Abstract
The invention discloses a waveguide phase measurement method and a waveguide phase measurement device for water content and flow of an oil well, which are used for integrally measuring the water content and the flow of crude oil by using a waveguide method and belong to the technical field of production logging. The casing of the logging instrument is used as a waveguide sensor, a plurality of receivers are sequentially arranged in the waveguide in the electromagnetic wave propagation direction, the phase characteristics of electromagnetic wave propagation on different waveguide lengths are respectively measured, the water content signals measured by the receivers are utilized, and the flow of the fluid medium is obtained through correlation function processing. The technical scheme provided by the invention can further improve the measurement precision of the water content of the oil-water medium in the oil well and the success rate of flow measurement.
Description
Technical Field
The invention belongs to the technical field of production logging, relates to a production profile logging technology of production logging, and particularly relates to a method and a device for synchronously measuring the moisture content and flow rate of crude oil in an oil well by using the same waveguide sensor.
Background
Production logging refers to downhole logging after injection and production well is put into operation, and production profile logging is to measure flow and water content on profiles of different depths in an oil well to obtain the properties and quantity of produced fluids in each layer.
At present, the measuring methods of the water content of oil wells at home and abroad mainly comprise a density method, an electrical parameter method and an electromagnetic wave method. The density method is divided into a radioactive density method and a differential pressure density method, and the density method is greatly influenced by gas and is not suitable for being applied to a low-yield degassing well. The electrical parameters are divided into a capacitance method, a resistance method and an electromagnetic wave method, wherein the capacitance method obtains the water content through the change of the dielectric constant of the crude oil and is suitable for measuring the oil as a continuous phase. The resistance method obtains the water content by measuring the change of the resistivity of the crude oil, and is suitable for water as a continuous phase. The electromagnetic wave method is suitable for both oil and water as continuous phases, and has the characteristic of measuring the water content of the oil well in a full range. Electromagnetic waves are further classified into reflection absorption methods and propagation property methods. Common sensors for electromagnetic wave propagation characteristics include coaxial lines and waveguides. The coaxial line phase method realizes the full-range measurement of the water content, is applied to oil fields, but has to improve the resolution of oil wells with extremely high water content, in addition, a turbine flowmeter is needed to measure the flow, and the success rate of well logging is reduced due to the fact that the turbine flowmeter is easy to sand jam and the like.
Disclosure of Invention
Aiming at the problems in the prior art, the invention provides a waveguide phase measurement method and device for the water content and the flow of an oil well, which is a technology for integrally measuring the water content and the flow of crude oil in the oil well by a waveguide method and can further improve the measurement precision of the water content of an oil-water medium in the oil well and the success rate of flow measurement.
The water detector (logging instrument) for logging the output profile of low-yield oil well is mainly composed of gas overflow collector, flowmeter and water content meter. The collector is the basis, and the flow velocity is improved after the flow is collected by the collector, especially the flow velocity of the lowest section. The accurate flow is surveyed to the measurement lower limit that can reach the flowmeter like this, then can provide the condition for surveying accurate moisture content, wherein the moisture content is the parameter of the most difficult accuracy of surveying.
The core of the invention is: the housing of the tool acts as a waveguide to act as a sensor for measuring water cut and flow. Transmitter generating ultra-high frequency electromagnetic wave (frequency)>300 MHZ), electromagnetic waves are guided in the waveguide as TE 10 Mode (rectangular waveguide) or TE 11 The mode (circular waveguide) is propagated, and fluid media such as oil, water and gas flow in the waveguide after being collected by the current collector and become carriers for propagating electromagnetic waves. Because the dielectric properties of oil gas and water are different greatly, the phase propagation properties of electromagnetic waves are different when fluid media with different water contents and gas holdup rates are propagated. The water content of the crude oil can be obtained by measuring the phase characteristics of the electromagnetic wave propagating in the waveguide and calculating. And a plurality of receivers are sequentially arranged in the waveguide in the electromagnetic wave propagation direction, the phase characteristics of the electromagnetic wave propagation on different waveguide lengths are respectively measured, and the water content signals measured by the receivers are processed by a correlation function, so that the flow of the fluid medium can be obtained. The method can also improve the measurement precision of the water content.
The technical scheme of the invention is as follows:
a waveguide phase measurement method for water content and flow of an oil well integrally measures the water content and flow of crude oil by using a waveguide method, and comprises the following steps:
1) The casing of the logging instrument is used as a waveguide sensor, an electromagnetic wave receiving probe is preset in the waveguide sensor, and the waveguide is used as a directional guide electromagnetic wave transmission mechanism and is a sensor for measuring the water content and the flow of an oil well; in the waveguide sensor, a plurality of receivers are sequentially arranged in the electromagnetic wave propagation direction and are used for respectively measuring the propagation phase characteristics of the electromagnetic wave on different waveguide lengths;
the waveguide may be a rectangular waveguide or a circular waveguide.
2) Generating ultra-high frequency electromagnetic waves in a waveguide with TE by means of a transmitter 10 Mode (rectangular waveguide) or TE 11 Mode (circular waveguide) propagation; using reference mode on phase measurementTo improve the accuracy of the phase measurement, the high frequency signal is mixed to reduce the frequency.
The transmitter generates two paths of electromagnetic waves, the first path of electromagnetic waves and a carrier signal generated by the local oscillator jointly enter the first frequency mixer for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; a second path of high-frequency electromagnetic waves of the transmitter are fed to a waveguide sensor (the medium is an oil-water mixture), the receiver receives an output signal from the waveguide sensor, the signal processed by the receiving circuit and a carrier signal generated by the local oscillator enter a second frequency mixer together for processing, and the processed signal is sent to a second input port of the phase discriminator; the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the electromagnetic waves are converted into pulse signals reflecting the water content through the integrating circuit and the pressure-frequency converter and transmitted to the ground by the aid of the logging cable.
The propagation process of the electromagnetic wave in the waveguide is as follows:
a) For a rectangular waveguide, according to maxwell's system of equations:
wherein,
is the rotation of the vector; h is the magnetic field strength, E is the electric field strength, μ is the magnetic permeability, ε is the dielectric constant, and ω is the electric field frequency. The formula (1) and the formula (2) can be obtained through derivation:
where k is the wave number in free space, k 2 ＝ω 2 με。
The vector wave equations of the formula (1) and the formula (2) are expanded in a rectangular coordinate system, a scalar Helmholtz equation set can be obtained according to the condition that each coordinate direction component is 0, two field components are selected to be solved, and the rest can be solved by using a first formula and a second formula of a Maxwell equation set.
Selecting a longitudinal component of the electromagnetic field taking into account the boundary conditions
And &>
From the sinusoidal time-varying assumption, the equation can be obtained as formula (3):
wherein β is a phase shift constant, and X (X) and Y (Y) are waveguide transverse distribution rules;
longitudinal component of electromagnetic field
And &>
In a rectangular coordinate system, can be expressed as:
order to
It is possible to obtain:
order to
Then:
in the waveguide, TE mode and TM mode are the main transmission modes, and TM mode is
The TE-type mode is
m and n are scalar numbers, both of which cannot be zeroed at the same time, and determine the standing wave number of the field magnitude x and y direction distributions. From formula (4):
in the formula (5), m is the half-cycle change number of the field in the x direction, and n is the half-cycle change number of the field in the y direction; the limit value is the phase shift constant β =0, whereby the wavelength:
in the formula (6), the longest mode of the cutoff wavelength in the rectangular cross-section waveguide is TE 10 ；λ c To limit the wavelength, λ c =2a; signals longer than this wavelength cannot propagate in the waveguide.
Similarly, for a circular waveguide, the limiting wavelength solution is:
wherein, P' mn Is the nth root of class I class m order Bessel functions.
3) Collecting fluids such as oil, water, gas and the like of an oil well through a collector, so that the fluids flow in a waveguide formed by a logging instrument shell and become carriers for transmitting electromagnetic waves; in specific implementation, the invention adopts an air-overflow collector.
4) Measuring the phase characteristics of the electromagnetic wave propagating in the waveguide by using an electromagnetic wave receiving probe (receiver) preset in the waveguide;
5) Calculating by using a mathematical model of the water content and the phase characteristics to obtain the water content of the crude oil;
6) A plurality of receivers are sequentially arranged in the waveguide in the electromagnetic wave propagation direction, and the propagation phase characteristics of the electromagnetic waves on different waveguide lengths are respectively measured;
7) And (3) measuring the time difference of the water content signals obtained by using a plurality of receivers, and processing through a correlation function to obtain the flow of the fluid medium.
Receivers of identical construction are mounted at two respective cross-sections along the waveguide at a known distance L. These two receivers are generally referred to as a first receiver and a second receiver, respectively, in terms of the direction of flow of the fluid. In operation, the two receivers receive electromagnetic waves emitted by the transmitter towards the fluid under test. When a measured fluid flows in the waveguide, random noise phenomena naturally occurring in the fluid, such as continuous generation and attenuation of turbulent flow "vortex" in a single-phase fluid, random variation of size distribution and spatial distribution of discrete phase particles in a two-phase fluid, random variation of local concentration of each component in a multi-phase component fluid, and the like, generate random modulation effects (amplitude modulation, phase modulation, or mixed modulation effect of the amplitude modulation and the phase modulation) on electromagnetic waves emitted by a transmitter. In turn, the sensitive components in the receiver detect the random noise signals caused by these modulation effects and produce corresponding changes in physical quantities (e.g., current, voltage, frequency, stress, etc.). Of course, the variation of these physical quantities over time will also be of a random nature. Finally, flow signals x (t) and y (t) related to the measured fluid flow condition can be extracted from the upstream and downstream sensors, respectively, by appropriate signal conversion circuitry, with t representing time.
When the measured fluid is in stable flow in the pipeline, the random flow noise signals x (t) and x (t) arey (t) can be considered as a stationary random process x from each epoch k (t) and { y k (t) } two sample functions.
The measuring system is a signal system which is composed of a first receiver, a second receiver, a waveguide tube and a measured fluid, and a random signal x (t) generated by the first receiver is used as the input of the system; the second receiver generates a random signal y (t) as an output of the system. The problem of determining the amount of time required for the fluid to flow through two cross-sections can then be attributed to the time required for a random signal to pass through a given system. The output signal y (t) of the system is cross-correlated with its input signal x (t) (essentially, the similarity of the waveforms of the two signals is compared at different delay values) to obtain a cross-correlation function R xy (τ) pattern. The time shift tau corresponding to the peak position of the pattern 0 Is the transit time of a random signal x (t) in the system, and therefore the propagation velocity v of the signal x (t) in the system c Can be calculated as follows:
v c ＝L/τ 0 formula (8)
Wherein v is c Is the relative propagation velocity. Tau. 0 Time displacement corresponding to the peak position of the graph; l is the distance between the upstream and downstream sensors;
under ideal flow conditions, i.e. when the flow velocities of the fluid at various points on the cross-section of the pipe are equal, the volume average flow velocity v of the measured fluid cp Can use the related flow velocity v c To indicate. Namely that
v cp ＝v c ＝L/τ 0 Formula (9)
Thus, the volumetric flow rate Q of the measured fluid can be expressed as
Q＝v c A formula (10)
Wherein A is the cross-sectional area of the sensor;
the invention adopts the related flow measurement system and method to realize the measurement of the flow speed or the volume flow rate of single-phase or two-phase fluid.
Theoretically, the cross-correlation between the random flow noise signals x (t) and y (t)Function R xy (τ) should be found on an infinite time average, i.e. at infinity
Wherein R is xy (τ, T) is a cross-correlation function; t is the average transfer time of the fluid flowing through the cross section of the upstream sensor and the downstream sensor;
in particular, in order to meet the requirement of measuring real-time performance, the operation of the cross-correlation function between the upstream and downstream flow noise signals x (t) and y (t) is allowed to be carried out only in a limited time interval. Thus, only the cross-correlation function R can be obtained as a result of each operation xy (τ) estimated value
The flow rate or volume flow of the fluid in the pipe can be measured using correlation methods.
The invention measures the mass flow of two-phase fluid by adding a densimeter.
Two control sections are arranged in a measuring pipe section and are separated by a small distance L, all phases cannot be mixed uniformly in two-phase flow in the pipe, and the distribution of the content of all phases is changed in the flowing process. The distance between the obtained quantity control cross sections is short, so that the distribution of the contents of the phases in the two-phase flow is not changed when the two-phase flow flows in the distance, for example, a detector is arranged at the first control cross section of the pipeline to measure the change curve X (t) of the content of one phase in the two phases along with the time, another detector is arranged at the second control cross section of the pipeline to measure the change curve Y (t) of the content of the same phase along with the time, X (t) and Y (t) are shown in a two-dimensional coordinate system, the distance delta t between the maximum value of the curve X (t) and the maximum value of the curve Y (t) is required for the fluid to flow from the first control cross section of the pipeline to the second control cross section, and the transverse direction in the coordinate system is transverse to the cross sectionThe coordinates are time, and the ordinate X (t) and Y (t) are the measured content values of one phase. After the time delta t of the length of the pipe section with the distance L for the fluid to flow is measured, the volume flow q of the two-phase fluid can be calculated according to the following formula v 。
Wherein A is the cross-sectional area of the pipeline; k-coefficient to account for speed deviation.
The correlation method is to determine the flow velocity of two phases by using the correlation between the content signals of certain phases measured on two cross sections. The advantage of using the correlation method to measure the two-phase flow is that the application range is wide, namely the method is suitable for gas-liquid two-phase fluid and is also suitable for various dirty fluid, slurry and liquid-solid two-phase flow.
Compared with the prior art, the invention has the beneficial effects that:
compared with a coaxial line sensor, the waveguide sensor saves a middle conducting line, and has simple structure and easy realization in the manufacturing process; the frequency of the transmitted electromagnetic wave is higher, and the resolution of the water content of the high water-bearing segment is improved. The multiple receivers can be arranged on different axial lengths of the waveguide to measure the phase change of the electromagnetic wave transmitted in the oil-water medium on different lengths in the waveguide, the flow of the fluid can be measured by utilizing the related technology, and the waveguide sensor realizes the integrated measurement of the water content and the flow. Because no movable part is arranged, sand jam of the turbine flowmeter is avoided, and the success rate of logging is improved. And the gas-overflowing type current collector is combined, so that the problem that the liquid phase flow cannot be accurately measured due to the influence of gas phase on the output profile of the low-yield oil well can be solved. The synchronous measurement and the simultaneous transmission of the flow signal and the moisture content signal provide favorable guarantee for the synchronous interpretation of the dynamically changed flow and the moisture content.
Drawings
FIG. 1 is a structural view of a rectangular waveguide and a circular waveguide;
in the figure, a is the length of the inner section of the rectangular waveguide, and b is the width of the inner section of the rectangular waveguide; r is the radius of the inner cross-section of the circular waveguide,
is the polar coordinate system angle; x, y and z respectively correspond to three axes of the rectangular space coordinate system.
FIG. 2 is a schematic diagram of an air flashing type current collector used in an embodiment of the present invention;
wherein, 1-umbrella rib; 2-liquid inlet; 3, umbrella cloth; 4-central tube.
FIG. 3 is a block diagram of a turbine flow meter used in an embodiment of the invention;
among them, 5-turbine blades; 6-Hall sensor; 7-turbine support; 8-magnetic steel.
FIG. 4 is a block diagram showing the structure of a water cut meter for measuring water cut by a waveguide method according to the present invention.
FIG. 5 is a schematic structural diagram of a flow measuring device for measuring flow by waveguide method provided by the invention;
in the figure, 9 — waveguide; 10-a transmitter; 11-the internal cross-section of the first receiving rectangular waveguide is long; 12 — second receiver.
FIG. 6 is a schematic diagram of a related flow meter utilized in an embodiment of the present invention;
in the figure, 13 — a first section of the waveguide; 14-second cross section of the waveguide.
FIG. 7 is a schematic flow chart of a correlation flow measurement method used in embodiments of the present invention;
in the figure, 15-measuring the first control section of the pipe; 16-measuring the second control section of the tube.
Fig. 8 is a graph of the relationship between the measured flow rate and the measured flow rate by using the correlation method according to the embodiment of the invention.
Detailed Description
The invention will be further described by way of examples, without in any way limiting the scope of the invention, with reference to the accompanying drawings.
The invention provides a method for synchronously measuring the water content and the flow of crude oil in an oil well by using the same waveguide sensor, which can be comprehensively applied to various types of oil wells and improves the measurement precision and the success rate of well logging.
A waveguide is a typical device of a microwave transmission line as a directional guide electromagnetic wave transmission mechanism. The transmission form of the guided electromagnetic wave is constrained by the boundary condition of a conductor or a medium, and the boundary condition and the boundary shape determine the electromagnetic field distribution rule, the existence condition and the propagation characteristic of the guided electromagnetic wave. Commonly used metal waveguides are of two basic types, rectangular and circular in cross-section, as shown in fig. 1. The oil-water-gas fluid medium flows in the waveguide and acts as a carrier for propagating electromagnetic waves. Measuring the phase characteristics of the electromagnetic wave propagation in the waveguide to obtain the water content, and performing correlation processing calculation on the time response of the phase characteristics of the electromagnetic wave propagated by the waveguide on different lengths to obtain the flow.
The measuring device for the water content and the flow waveguide phase of the oil well specifically adopted by the invention comprises a waveguide sensor, a transmitter, a multi-pole receiver, a local vibrator, a frequency mixer, a phase discriminator and the like, wherein a plurality of paths of phase characteristic signals are transmitted to ground equipment by a logging cable after being subjected to data transmission short circuit, and then are subjected to various treatments to obtain the water content and the flow.
The transmitter generates two paths of electromagnetic waves, the first path of electromagnetic waves and a carrier signal generated by the local oscillator jointly enter the first frequency mixer for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; a second path of high-frequency electromagnetic waves of the transmitter are fed to a waveguide sensor (the medium is an oil-water mixture), the multi-pole receiver receives an output signal from the waveguide sensor, the signal processed by the receiving circuit and a carrier signal generated by the local oscillator enter a second frequency mixer together for processing, and the processed signal is sent to a second input port of the phase discriminator; the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the electromagnetic waves are transmitted to the ground by the logging cable through the integrating circuit and the pressure-frequency converter.
The waveguide may be a rectangular waveguide or a circular waveguide. The waveguide is used for guiding electromagnetic waves to transmit along a certain direction and is called a guided wave system, the electromagnetic waves guided by the guided wave system are called guided waves, and the transmission of the guided waves is restricted by boundary conditions of a conductor and a medium. At the same time, the oil-water fluid medium after collecting is restrained.
Fig. 2 is a structural diagram of an air-bleeding type current collector used in the embodiment of the present invention, as shown in fig. 2, the measurement result of the flow rate and the water content are seriously influenced by the gas in the oil well, compared with the ordinary current collector, the air-bleeding type current collector is moved down to the position of a liquid inlet 2, and when the umbrella cloth 1 of the current collector is opened, the liquid inlet 2 of a central tube 3 is positioned below the plane enclosed by the umbrella cloth bottom ends. The structure of the gas overflow collector can separate gas from liquid, so that a very small part of gas and almost all liquid pass through the device, and the influence of gas generated by an oil well on liquid phase flow and measurement can be greatly eliminated.
As shown in fig. 3, the turbine flowmeter belongs to a speed flowmeter, when a fluid passes through a turbine flowmeter sensor, under the action of the fluid, the turbine blade 5 is forced to rotate, the rotation speed of the turbine blade is in direct proportion to the average flow speed, and meanwhile, magnetic lines of force generated by the blade magnetic steel cut the hall sensor 6 to generate a potential signal, so that flow information can be obtained according to the change of the potential signal. The turbine blade is a movable part and is easy to be stuck, so that the success rate is influenced.
As shown in fig. 4, the system for measuring the water content of crude oil by using the electromagnetic wave propagation method provided by the invention comprises: the device comprises a waveguide sensor, a transmitter, a multipole receiver, a local oscillator, a mixer, a phase discriminator, an integrator and a voltage-frequency converter; the phase measurement adopts a reference mode, and in order to improve the accuracy of the phase measurement, a high-frequency signal is subjected to frequency mixing to reduce the frequency. The transmitter generates two paths of electromagnetic waves, the first path of electromagnetic waves and a carrier signal generated by the local oscillator jointly enter the first frequency mixer for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; a second path of high-frequency electromagnetic waves of the transmitter are fed to a waveguide sensor (the medium is an oil-water mixture), the receiver receives an output signal from the waveguide sensor, the signal processed by the receiving circuit and a carrier signal generated by the local oscillator enter a second frequency mixer together for processing, and the processed signal is sent to a second input port of the phase discriminator; the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the electromagnetic waves are transmitted to the ground by the integral circuit and the pressure frequency converter through the logging cable.
As shown in fig. 5, knowing the inner diameter R of the waveguide sensor, the measured phase characteristics of the receiver 11 and the receiver 12 are calculated by cross-correlation, so that the time of flowing through the two receivers can be obtained, and the flow rate can be calculated.
The propagation process of the electromagnetic wave in the waveguide of the present invention is as follows:
a) For a rectangular waveguide, according to maxwell's system of equations:
wherein,
is the rotation of the vector; h is the magnetic field strength, E is the electric field strength, μ is the magnetic permeability, ε is the dielectric constant, and ω is the electric field frequency. Equations (1) and (2) can be obtained by derivation:
where k is the wave number in free space, k 2 ＝ω 2 με。
The vector wave equations of the formula (1) and the formula (2) are expanded in a rectangular coordinate system, a scalar Helmholtz equation set can be obtained according to the condition that each coordinate direction component is 0, two field components are selected to be solved, and the rest can be solved by using a first formula and a second formula of a Maxwell equation set.
Selecting a longitudinal component of the electromagnetic field taking into account the boundary conditions
And &>
According to sine time-varying assumptionThe equation can be obtained as in equation (3):
where β is the phase shift constant and X (X) and Y (Y) are the waveguide transverse distribution laws.
Longitudinal component of electromagnetic field
And &>
In a rectangular coordinate system, can be expressed as:
order to
It is possible to obtain:
order to
Then:
in the waveguide, TE mode and TM mode are main transmission modes, and TM mode is
The TE mode is
m and n are scalar numbers, both of which cannot simultaneously zeroAnd determines the standing wave number of the field magnitude x and y direction distributions. From formula (4): />
In the formula (5), m is the half-cycle change number of the field in the x direction, and n is the half-cycle change number of the field in the y direction; the limit value is the phase shift constant β =0, whereby the wavelength can be limited:
in the formula (6), the longest mode of the cutoff wavelength in the rectangular cross-section waveguide is TE 10 ；λ c Is a limit wavelength, λ c =2a; signals longer than this wavelength cannot propagate in the waveguide.
Similarly, for a circular waveguide, the limiting wavelength solution is:
wherein P' mn Is the nth root of class I class m order Bessel functions.
b) The transmitter generates two paths of electromagnetic waves, the first path of electromagnetic waves and a carrier signal generated by the local oscillator jointly enter the first frequency mixer for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; a second path of high-frequency electromagnetic waves of the transmitter are fed to a waveguide sensor (the medium is an oil-water mixture), the multi-pole receiver receives an output signal from the waveguide sensor, the signal processed by the receiving circuit and a carrier signal generated by the local oscillator enter a second frequency mixer together for processing, and the processed signal is sent to a second input port of the phase discriminator; the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the electromagnetic waves are transmitted to the ground by the logging cable through the integrating circuit and the pressure-frequency converter.
As shown in fig. 6, a schematic diagram of a related flow meter used in an embodiment of the invention.
At two sections 13 and 14, separated by a known distance L along the waveguide, receivers of identical construction are mounted respectively. These two receivers are generally referred to as a first receiver and a second receiver, respectively, in terms of the direction of flow of the fluid. In operation, the two receivers receive electromagnetic waves emitted by the transmitter towards the fluid under test. When a measured fluid flows in the waveguide, random noise phenomena naturally occurring in the fluid, such as continuous generation and attenuation of turbulent flow "vortex" in a single-phase fluid, random variation of size distribution and spatial distribution of discrete phase particles in a two-phase fluid, random variation of local concentration of each component in a multi-phase component fluid, and the like, generate random modulation effects (amplitude modulation, phase modulation, or mixed modulation effect of the amplitude modulation and the phase modulation) on electromagnetic waves emitted by a transmitter. In turn, the sensitive components in the receiver detect the random noise signals caused by these modulation effects and produce corresponding changes in physical quantities (e.g., current, voltage, frequency, stress, etc.). Of course, the variation of these physical quantities over time will also be of a random nature. Finally, flow signals x (t) and y (t) relating to the measured fluid flow conditions can be extracted from the upstream and downstream sensors, respectively, by appropriate signal conversion circuitry.
When the measured fluid is in stable flow in the pipeline, the random flow noise signals x (t) and y (t) can be respectively regarded as smooth random processes x from each state history k (t) and { y k (t) } two sample functions.
If the system which is enclosed by the dotted line in FIG. 6 and consists of the first receiver, the second receiver, the waveguide and the measured fluid is regarded as a signal system, and the random signal x (t) generated by the first receiver is taken as the input of the system; the second receiver generates a random signal y (t) as an output of the system. The problem of determining the amount of time required for the fluid to travel from section 13 to section 14 can then be attributed to the time required for a random signal to pass through a given system. The output signal y (t) of the system is cross-correlated with its input signal x (t)The cross-correlation function R is obtained by calculation (essentially, comparing the similarity of the two signal waveforms at different delay values) xy (τ) pattern. Time shift tau corresponding to the peak position of the pattern 0 Is the transit time of a random signal x (t) in the system, and therefore the propagation velocity v of the signal x (t) in the system c Can be calculated as follows
v c ＝L/τ 0 (8)
Generally, it is called v c Is the relative velocity.
Under ideal flow conditions, i.e. when the flow velocities of the fluid at various points on the cross-section of the pipe are equal, the volume average flow velocity v of the measured fluid cp The relative flow velocity v can be used c To indicate. Namely, it is
v cp ＝v c ＝L/τ 0 (9)
Thus, the volumetric flow rate Q of the measured fluid can be expressed as
Q＝v c ·A (10)
The foregoing description is only illustrative of the principles of the related flow measurement technology, but is not intended to be exhaustive or to limit the invention to the precise form disclosed. In practice, there are many factors that need to be considered in the design and use of the relevant flow measurement system to achieve a measurement of the flow rate or volumetric flow rate of a single or two-phase fluid.
Theoretically, the cross-correlation function R between the random flow noise signals x (t) and y (t) xy (τ) should be found on an infinite time average, i.e. at infinity
However, in practical systems, the operation of the cross-correlation function between the upstream and downstream flow noise signals x (t) and y (t) is allowed to be performed only for a limited time interval in order to meet the requirements of measuring real-time. Thus, only the cross-correlation function R can be obtained as a result of each operation xy (τ) estimated value
The flow velocity or volume flow of the fluid in the pipeline can be measured by applying a correlation method, and if the mass flow of the two-phase fluid is to be measured, a densimeter is required to be additionally arranged.
Fig. 7 is a schematic diagram of related-method flow measurement adopted by the embodiment of the invention.
Fig. 8 is a graph showing the relationship between the measured flow rate and the measured flow rate by using the correlation method according to the embodiment of the present invention.
The operation of the associated flow meter is shown in fig. 7. Two control interfaces 15 and 16 are provided in the measuring pipe section, which are separated by a small distance L, in the two-phase flow in the pipe, the phases cannot be mixed very uniformly, and the distribution of the content of each phase varies during the flow. Since the distance between the obtained quantity control sections is very short, it can be considered that the distribution of the contents of the phases in the two-phase flow is not changed when the two-phase flow flows within the distance, for example, a detector is arranged at the first control section 15 of the pipeline to measure the change curve X (t) of the content of one phase in the two phases with time, another detector is arranged at the second control section 16 of the pipeline to measure the change curve Y (t) of the content of the same phase with time, and X (t) and Y (t) are shown in fig. 8, it can be seen from the figure that the distance Δ t between the highest value of the curve X (t) and the highest value of the curve Y (t) should represent the time required for the fluid to flow from the first control section 15 to the second control section 16 of the pipeline, in fig. 8, the abscissa is time, and the ordinate X (t) and Y (t) are the measured content values of the one phase. After the time delta t of the length of the pipe section with the flowing distance L of the fluid is measured, the volume flow q of the two-phase fluid can be calculated according to the following formula v 。
Wherein A is the cross-sectional area of the pipeline;
k-coefficient to account for speed deviation.
This measurement method is called correlation method, and uses the correlation between the content signals of certain phases measured on two cross sections to determine the flow velocity of two phases. The advantage of using the correlation method to measure the two-phase flow is that the application range is wide, namely the method is suitable for gas-liquid two-phase fluid and is also suitable for various dirty fluid, slurry and liquid-solid two-phase flow.
It is noted that the disclosed embodiments are intended to aid in further understanding of the invention, but those skilled in the art will appreciate that: various substitutions and modifications are possible without departing from the spirit and scope of this disclosure and the appended claims. For example, the same apparatus and method can be applied to alkali metal atoms such as rubidium, potassium, sodium, etc. Therefore, the invention should not be limited by the disclosure of the embodiments, but should be defined by the scope of the appended claims.
Claims (10)
1. A waveguide phase measurement method for water content and flow of an oil well integrally measures the water content and flow of crude oil by using a waveguide method, and comprises the following steps:
1) The method comprises the following steps of taking a shell of a logging instrument as a waveguide sensor, presetting an electromagnetic wave receiving probe in the waveguide sensor, and directionally guiding electromagnetic wave transmission by using the waveguide sensor as a sensor for measuring the water content and the flow of an oil well; in the waveguide sensor, multipole receivers are sequentially arranged in the electromagnetic wave propagation direction;
2) Generating ultrahigh frequency electromagnetic waves by using a transmitter, and transmitting the ultrahigh frequency electromagnetic waves in the waveguide sensor; performing phase measurement in a reference mode, and performing frequency mixing and frequency reduction on an ultrahigh frequency electromagnetic wave signal;
the transmitter generates two paths of electromagnetic waves, the first path of ultrahigh frequency electromagnetic waves and a carrier signal generated by the local oscillator enter the first frequency mixer together for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; feeding a second path of ultrahigh frequency electromagnetic waves generated by the transmitter to the waveguide sensor, wherein the medium is an oil-water mixture;
the multi-pole receiver receives an output signal from the waveguide sensor, the signal processed by the receiving circuit and a carrier signal generated by the local oscillator jointly enter the second frequency mixer for processing, and the processed signal is sent to the second input port of the phase discriminator;
the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the signals are converted into pulse signals reflecting the water content through the integrating circuit and the pressure frequency converter in sequence and transmitted to the ground through a logging cable;
3) Collecting the fluid of the oil well through a collector, so that the fluid flows in a waveguide sensor formed by a casing of the logging instrument and becomes a carrier for transmitting electromagnetic waves;
4) Measuring the phase characteristics of the electromagnetic waves propagated in the waveguide sensor by using an electromagnetic wave receiving probe preset in the waveguide sensor;
5) Calculating by using a model method of water content and phase characteristics to obtain the water content of the crude oil;
6) In the waveguide sensor, through the arranged multipole receiver, the propagation phase characteristics of the electromagnetic waves on different waveguide lengths are respectively measured;
7) Calculating and processing the time difference of the water content signal obtained by measuring by using a multipole receiver by using a correlation method to obtain the flow of the fluid medium;
through the steps, the water content and the flow of the crude oil are integrally measured by using a waveguide method.
2. The waveguide phase measurement method for water content and flow rate of oil well as claimed in claim 1, wherein step 7) comprises the following steps:
71 A signal system is composed of a transmitter, a multipole receiver, a waveguide sensor and a measured fluid, wherein the multipole receiver receives electromagnetic waves sent to the measured fluid by the transmitter:
respectively installing a multi-pole receiver at the cross section with the distance of L in the waveguide sensor, and detecting random noise signals by the multi-pole receiver when the measured fluid flows in the waveguide sensor and generating corresponding physical quantity change; extracting flow signals x (t) and y (t) of the measured fluid from the upstream sensor and the downstream sensor respectively through signal conversion;
72 When the measured fluid is flowing steadily, the flow signals x (t) and y (t) are stationary random processes x from each history k (t) and { y k (t) } two sample functions; x (t) is input; y (t) is output;
73 The output signal y (t) and the input signal x (t) are cross-correlated to obtain a cross-correlation function R xy (τ) a pattern;
74 According to R) xy (tau) the propagation velocity v of the signal x (t) is calculated by means of a graph c ；v c The volume flow rate Q of the measured fluid is further calculated according to the related flow velocity or the volume average flow velocity of the measured fluid;
75 The mass flow of the two-phase fluid is also determined by calculation.
3. The method of waveguide phase measurement of water cut and flow rate in oil wells of claim 2, wherein step 73) calculates the cross-correlation function R xy (τ) estimated value
As a function of the cross-correlation R xy (τ)：
Wherein T is the average transfer time of the fluid flowing through the cross section of the upstream sensor and the downstream sensor;
step 74), the propagation velocity v of the signal x (t) c Calculated according to equation (8):
v c ＝L/τ 0 formula (8)
Wherein, tau 0 Time displacement corresponding to the peak position of the graph; l is the distance between the upstream and downstream sensors;
volume average flow velocity v of measured fluid cp By related flow velocity v c Represents;
the volumetric flow rate Q of the measured fluid is expressed by equation 10:
Q＝v c a formula (10)
Wherein A is the cross-sectional area of the pipeline.
4. The waveguide phase measurement method for water content and flow rate of oil well according to claim 2, wherein in step 75), the volume flow rate q of two-phase fluid is calculated by the formula (13) v ：
Wherein A is the cross-sectional area of the pipeline; k is the coefficient of the speed deviation.
5. The waveguide phase measurement method for water cut and flow rate of oil well as claimed in claim 2, wherein,
when the mass flow of the two-phase fluid is measured, a densimeter is also needed to be additionally arranged.
6. The waveguide phase measurement method for water content and flow rate of oil well as claimed in claim 1, wherein the waveguide sensor is a rectangular waveguide or a circular waveguide; ultra-high frequency electromagnetic wave generated by transmitter is TE in waveguide sensor 10 Mode rectangular waveguide or TE 11 Mode circular waveguide propagation.
7. The waveguide phase measurement method for water content and flow rate of oil well as claimed in claim 1, wherein in step 2), the propagation process of electromagnetic wave in the waveguide sensor is as follows:
21 For a rectangular waveguide, according to maxwell's system of equations:
wherein,
is the rotation of the vector; h is magnetic field intensity, E is electric field intensity, mu is magnetic permeabilityThe coefficient, ε is the dielectric constant, ω is the electric field frequency; vector fluctuation equations (1) and (2) can be obtained:
where k is the wave number in free space, k 2 ＝ω 2 με；
22 Expanding the formula (1) and the formula (2) in a rectangular coordinate system to obtain a scalar Helmholtz equation set;
selecting a longitudinal component of the electromagnetic field taking into account the boundary conditions
And &>
The equation is obtained according to the sine time-varying assumption as formula (3):
wherein β is a phase shift constant, and X (X) and Y (Y) are waveguide transverse distribution rules;
23 Longitudinal component of the electromagnetic field
And &>
Expressed in a rectangular coordinate system as: />
Order to
Obtaining:
order to
Then:
in the waveguide, it can be obtained by formula (4):
in the formula (5), m is the half-cycle change number of the field in the x direction, and n is the half-cycle change number of the field in the y direction; the threshold value is a phase shift constant beta; a is the length of the inner section of the rectangular waveguide; b is the width of the inner section of the rectangular waveguide;
the limit wavelength is solved according to equation (5), and is expressed as equation (6):
in formula (6), λ c A limit wavelength;
for a circular waveguide, its bound wavelength solution is expressed as equation (7):
wherein, P' mn Is of the class IThe nth root of the order m Bessel function; and R is the radius of the inner section of the circular waveguide.
8. The waveguide phase measuring device for the water content and the flow of the oil well for realizing the waveguide phase measuring method for the water content and the flow of the oil well according to the claim 1 is characterized by comprising a waveguide sensor, a transmitter, a multi-pole receiver, a local oscillator, a mixer and a phase discriminator; the mixer comprises a first mixer and a second mixer;
the transmitter generates two paths of electromagnetic waves, the first path of electromagnetic waves and a carrier signal generated by the local oscillator jointly enter the first frequency mixer for processing, and the output of the first frequency mixer is sent to the first input port of the phase discriminator; feeding a second path of high-frequency electromagnetic waves of the transmitter to the waveguide sensor, wherein the medium is an oil-water mixture; the multi-pole receiver receives an output signal from the waveguide sensor, and the signal processed by the receiving circuit and a carrier signal generated by the local oscillator jointly enter the second mixer for processing; the processed signal is sent to a second input port of the phase discriminator; the two paths of signals are processed by the phase discriminator to obtain the phase characteristics of the electromagnetic waves when the electromagnetic waves are transmitted in the oil-water mixed medium in the coaxial line sensor, and then the electromagnetic waves are transmitted to the ground by the logging cable through the integrating circuit and the voltage-frequency converter.
9. The waveguide phase measurement device for water cut and flow rate of oil well according to claim 8, wherein the fluid in the oil well is collected by a collector.
10. The waveguide phase measurement device for water content and flow rate of oil well as claimed in claim 9, wherein the collector is an air-bleed collector.
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| CN113985060B (en) * | 2021-10-31 | 2024-08-23 | 天津职业技术师范大学(中国职业培训指导教师进修中心) | Cross-correlation velocity measurement method reflecting peak type characteristics of cross-correlation function |
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| CN115201226B (en) * | 2022-07-11 | 2024-10-01 | 天津大学 | Oil-water two-phase flow double-parameter measurement method |
| CN117888897A (en) * | 2024-03-15 | 2024-04-16 | 西安思坦仪器股份有限公司 | Glue cylinder flow collecting type flow water-containing instrument |
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