An apparatus for detecting crude oil parameters

Abstract

The present invention relates to an apparatus for detecting crude oil parameters. The apparatus includes a liquid chamber formed by a first housing, a flow measurement chamber formed by a second housing, a detection chamber formed by a third housing, and a processing module. The flow measurement chamber is disposed inside the liquid chamber. The first housing includes a first liquid inlet and a first liquid outlet. The second housing includes a second liquid inlet and a second liquid outlet. The second liquid outlet is communicated with the first liquid outlet through a liquid outlet pipeline. A float assembly is disposed inside the flow measurement chamber, which includes a float and a float connecting rod integrally connected thereto. The end of the float connecting rod is connected to a detection portion. The detection chamber internally includes at least a position detection module, which obtains a float height detection signal by detecting the position of the detection portion at the end of the float connecting rod. The processing module calculates the flow rate of the measured crude oil according to the float height detection signal. The present invention can safely measure the flow rate of crude oil in a crude oil transportation pipeline and meet the crude oil measurement accuracy.

Description

Technical Field

[0001] The present invention relates to a detection device in the oil field, and particularly to a crude oil parameter detection device. Background Art

[0002] During the oil extraction process, surface oil production equipment, such as pumping units, extracts a mixture of oil, gas, and water (hereinafter referred to as crude oil) from the formation and transports it through surface pipelines to a crude oil processing plant for processing or to an oil storage tank for temporary storage. In order to understand the production of an oil well, relevant equipment is needed to measure the production of the oil well. In theory, flow meters such as vortex flow meters, ultrasonic flow meters, and metal float flow meters can be installed in the oil pipeline to measure the crude oil flow rate, and then the production of the oil well can be obtained through conversion. However, in actual applications, the flow characteristics of the crude oil in the surface pipeline of the oil well are closely related to the liquid output mode of the oil well. The working process of the oil production equipment includes two strokes, the upstroke and the downstroke. During the upstroke, the crude oil flows out through the sucker rod to the surface pipeline. During the downstroke, basically no crude oil flows out. Therefore, the liquid in the surface pipeline of the oil well flows in pulses. In addition, the freshly extracted and untreated crude oil itself has a complex composition and is a mixed liquid integrating oil, gas, water, and various other liquid components and solid particles. It is viscous, has poor fluidity, and there will also be agglomerated oil blocks in the liquid. If the above-mentioned vortex flow meters, ultrasonic flow meters, turbine flow meters, metal float flow meters and other devices are used to measure the flow rate in the surface pipeline of the oil well, firstly, due to the unique liquid output mode of the oil well, the measurement error will be too large to meet the accuracy requirements. Secondly, due to the liquid properties of the crude oil, it is very easy to block the measuring tube of the flow meter, which not only causes the inability to measure, but also easily leads to an increase in the pressure in the pipeline, bursting the pipeline, and causing safety accidents such as oil leakage and pipeline explosion. Therefore, there is an urgent need for a flow measurement device that is safe, easy to install, and meets the accuracy requirements. In addition, in order to obtain other parameters of the oil pipeline, such as pipeline pressure and water content of the crude oil in the pipeline, the current common practice is to drill holes in the oil pipeline to install these parameter detection devices, and the installation position is random and the types of data obtained are single. Summary of the Invention

[0003] Aiming at the technical problems existing in the prior art, the present invention provides a crude oil parameter detection device, which can safely measure the crude oil flow rate in the crude oil transportation pipeline and meet the accuracy requirements of crude oil measurement.

[0004] To solve the above technical problems, the present invention provides a device for detecting crude oil parameters, which includes a liquid chamber, a flow measurement chamber, a float assembly, a detection chamber, a connecting member, a position detection module, and a processing module; wherein, the liquid chamber is constituted by a first housing and includes a first liquid inlet and a first liquid outlet; the flow measurement chamber is constituted by a second housing and is built in the liquid chamber, which includes a second liquid inlet and a second liquid outlet, and the second liquid outlet is communicated with the first liquid outlet through a liquid outlet pipe; the float assembly is built in the flow measurement chamber and includes a float and a float connecting rod integrally connected thereto, and the end of the float connecting rod is connected to a detection part; the detection chamber is constituted by a third housing and internally includes at least a position detection module; the upper part of the connecting member is fixed to the third housing constituting the detection chamber, and its lower part is respectively connected to the first housing constituting the liquid chamber and the second housing constituting the flow measurement chamber, and a through hole is provided on the connecting member, and the end of the float connecting rod can extend out of the detection chamber through the through hole; the processing module is at least connected to the position detection module. When the detection part at the end of the float connecting rod extends into the detection chamber, the position detection module obtains a float height detection signal by detecting the position of the detection part at the end of the float connecting rod; the processing module calculates the flow rate of the measured crude oil according to the float height detection signal.

[0005] Preferably, the device for detecting crude oil parameters further includes a gas separation structure, which includes a gas separation partition built in the liquid chamber, which is placed between the second housing and the first housing and is provided with a plurality of air permeable holes thereon; an air inlet opened on the first housing between the gas separation partition and the lower surface of the connecting member; an air outlet opened on the liquid outlet pipe located outside the liquid chamber; both ends of the gas pipe are respectively connected to the air inlet and the air outlet through interfaces.

[0006] Preferably, the device for detecting crude oil parameters further includes a pressure sensor, which is configured to be installed on the upper part of the connecting member, and its pressure sensing part penetrates through the connecting member and communicates with the liquid chamber; its signal end is connected to the processing module, and the processing module calculates the current pipeline pressure according to the pressure sensing signal sent by the pressure sensor, or receives the pressure value data sent by the pressure sensor.

[0007] Preferably, the device for detecting crude oil parameters further includes a water content detection device, whose connecting seat is installed on the first housing constituting the liquid chamber, its water content sensing end is built in the liquid chamber, and its signal is connected to the processing module, and the processing module calculates the current water content according to the water content sensing signal sent by the water content detection device, or receives the water content data sent by the water content detection device.

[0008] In the present invention, during the flow of the measured crude oil from the liquid inlet to the liquid outlet of the measuring pipe, the float can overcome the resistance generated by the viscosity of the crude oil and rise, stabilize at a certain height, descend, then rise again, stabilize at a certain height, and then descend again, etc., following the flow pattern (the crude oil flows in strands). Also, when the crude oil is flowing continuously, it can stabilize at different heights according to the flow rate. Therefore, the crude oil parameter detection device provided by the present invention can well adapt to the flow characteristics of the crude oil and the properties of the crude oil liquid. In addition, the present invention does not use the transmission mechanism in the traditional float flowmeter, so it is not limited by the fatigue damage of the traditional float detection component, and the reliability and accuracy of the long-term measurement of the device can be ensured. Moreover, the parameter detection device provided by the present invention is small in volume, occupies little space, is convenient for installation and daily maintenance, and can integrate other parameter detection devices according to the actual application requirements, so as to be able to detect multiple data. The structure of the device is strong and durable, and it can be applied to various field environments and work stably for a long time. BRIEF DESCRIPTION OF THE DRAWINGS

[0009] Next, the preferred embodiments of the present invention will be further described in detail with reference to the drawings, where:

[0010] Figure 1 is a schematic external structure diagram of a crude oil parameter detection device according to an embodiment of the present invention;

[0011] Figure 2 is according to Figure 1 the exploded view of the structure of the crude oil parameter detection device of the shown embodiment;

[0012] Figures 3 - 4 is a partial cross-sectional view of the crude oil parameter detection device according to the present embodiment of the present invention;

[0013] Figure 5 is a schematic diagram of a float connecting rod according to an embodiment of the present invention;

[0014] Figure 6 is a schematic block diagram of the control device of a crude oil parameter detection device according to an embodiment of the present invention;

[0015] Figure 7 is a schematic structure diagram of a position detection module according to an embodiment of the present invention;

[0016] Figure 8 is to Figure 6 the schematic diagram after expanding the six Hall sensor arrays in

[0017] Figure 9 is a schematic diagram of the calculation principle of a crude oil parameter detection device according to an embodiment of the present invention;

[0018] Figure 10Schematic diagram of the calculation principle of the crude oil parameter detection device according to another embodiment of the present invention;

[0019] Figure 11 Schematic diagram of the external structure of the crude oil parameter detection device according to another embodiment of the present invention;

[0020] Figure 12 is Figure 11 Schematic diagram of the structural decomposition of the crude oil parameter detection device shown;

[0021] Figure 13 Partial cross-sectional view of the crude oil parameter detection device according to one embodiment of the present invention;

[0022] Figures 14A - 14C Partial cross-sectional schematic diagram of the crude oil parameter detection device according to another three embodiments of the present invention; and

[0023] Figures 15A - 15B Schematic diagram of the arrangement of photoelectric sensors according to two embodiments of the present invention. Detailed implementation manners

[0024] For the purposes of making the objectives, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. Apparently, the described embodiments are some, but not all, of the embodiments of the present invention. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without making creative efforts shall fall within the scope of protection of the present invention.

[0025] In the following detailed description, reference may be made to the various specification drawings which form a part of this application and which illustrate specific embodiments of the application. In the drawings, like reference numerals generally describe substantially similar components in different diagrams. The various specific embodiments of the present application have been described in sufficient detail below to enable those of ordinary skill in the relevant art and technology to implement the technical solutions of the present application. It should be understood that other embodiments may also be utilized or structural, logical or electrical changes may be made to the embodiments of the present application.

[0026] The present invention provides an apparatus for detecting crude oil parameters. One of the basic detection parameters is the flow rate of the connected crude oil pipeline. The rising height of the float in the measuring tube is determined by detecting the position of the detection part on the float connecting rod, and thus the flow rate of the measured crude oil is calculated. Among existing flow measurement devices, the float flowmeter is a widely used gas and liquid flow measurement device. The metering element of the float flowmeter includes a measuring tube and an indicator. The inside of the measuring tube is a conical measuring chamber that gradually expands from bottom to top. Its lower end is the fluid inlet, and its upper end is the fluid outlet. A float that can move freely up and down under the guidance of a guide rod is placed inside the conical measuring chamber. When the measured fluid flows through the conical measuring tube from bottom to top, a differential pressure is generated between the upper and lower ends of the float to form an upward force. When the upward force acting on the float is greater than the weight of the float immersed in the fluid, the float rises. The annular gap area between the float and the inner wall of the measuring tube increases accordingly, and the fluid velocity at the annular gap immediately decreases. The differential pressure between the upper and lower ends of the float decreases, and the upward force acting on the float also decreases until the upward force is equal to the weight of the float immersed in the fluid, at which point the float stabilizes at a certain height and the annular gap area between the float and the inner wall of the measuring tube remains constant. The annular gap area is related to the rising height of the float, that is, the position where the float rises in the measuring tube represents the magnitude of the flow rate. There are generally two types of indicators. One type is to set scales on the tube body, and the scale values are determined according to the corresponding relationship between the position and the flow rate. The flow rate value can be obtained by observing the scale position where the liquid is located for this type of flowmeter. The other type of indicator is a pointer-type indicator. In this type of flowmeter, a first permanent magnet is built into the float, and a second permanent magnet that is magnetically coupled to the first permanent magnet is built into the indicator. The second permanent magnet is connected to the pointer through a transmission mechanism such as a connecting rod. When the float moves up and down and rotates with the measured fluid, the magnetic field generated by the first permanent magnet built into the float changes with the movement and rotation of the float. Since the second permanent magnet in the indicator is magnetically coupled to the first permanent magnet, the second permanent magnet rotates under the change of the magnetic field, and the second permanent magnet drives the pointer of the indicator to rotate through the connecting rod serving as the transmission mechanism. After calibration, the rising height of the float corresponds one-to-one with the position of the pointer, and the position of the pointer indicates the corresponding flow rate. However, after long-term use of the above-mentioned metal float flowmeter, due to the limitations of processing and material conditions, the connecting rod in the transmission mechanism will suffer fatigue damage and cannot accurately transmit the position of the float, resulting in inaccurate measurement and poor reliability after long-term use. The present invention does not use a transmission mechanism, so it is not limited by the fatigue damage of the traditional float position detection components and can ensure accuracy during long-term use. In addition, the traditional float has a small mass and cannot adapt to crude oil, which is a fluid with complex composition and high viscosity. In order to adapt to the special flow state and fluid composition of crude oil, the device provided by the present invention is significantly different from the traditional float flowmeter in structure. The following details the present invention through specific embodiments.

[0027] Figure 1 is a schematic external structure diagram of an apparatus for detecting crude oil parameters according to an embodiment of the present invention, Figure 2Yes Figure 1 Exploded view of the crude oil parameter detection device in the embodiment shown Figures 3 - 4 Partial cross-sectional view of the crude oil parameter detection device in this embodiment. Combining Figures 1 - 4 , the crude oil parameter detection device in this embodiment includes a liquid chamber 10 formed by a first housing 1. A first liquid inlet and a first liquid outlet are provided on the first housing 1. The first liquid inlet is connected to a liquid inlet connector 11, and the first liquid outlet is connected to a liquid outlet connector 12. The liquid inlet connector 11 and the liquid outlet connector 12 include pipes and flanges, and the flanges can be connected to the oil pipeline. A flow measurement chamber 20 formed by a second housing 2 is arranged inside the liquid chamber 10. A second liquid inlet is opened at the bottom of the second housing 2, and a second liquid outlet is opened on the side. The pipe of the liquid outlet connector 12 extends into the liquid chamber 10 and is connected to the second liquid outlet. When the crude oil in the oil pipeline enters the liquid chamber 10 through the liquid inlet connector 11, then enters the flow measurement chamber 20 through the second liquid inlet at the bottom of the second housing 2, and then is output to the oil pipeline through the second liquid outlet and the liquid outlet connector 12.

[0028] A conical tube 21 is nested inside the second housing 2. The cone angle of the conical tube 21 is not greater than 20 degrees. By changing the cone angle of the conical tube 21, different flow rates can be adapted. A float assembly is arranged inside the conical tube 21, which includes a float 22 and a float connecting rod 23 integrally connected thereto. The end of the float connecting rod 23 is connected to a detection part. In a better embodiment, in order to stabilize the moving path of the float in the vertical direction when moving, the end of the float connecting rod 23 is connected to a float stabilizing structure 24. Refer to Figure 5 shown, which is a schematic diagram of the float connecting rod 23. The float stabilizing structure 24 includes a column body and a plurality of side edges protruding from the side surface of the column body along the axial direction of the column body. There are 4 side edges in this embodiment. Looking at the cross-section of the column body, the 4 side edges form a cross structure. The float in this embodiment is a floating ball made of metal, and its diameter is larger than the second liquid inlet on the conical tube 21.

[0029] The first housing 1 and the second housing 2 are fixed to the lower part of the connecting seat 4. As a connecting member, the upper part of the connecting seat 4 is fixed to the third housing 3, and the interior of the third housing 3 constitutes a detection chamber 30. The connecting seat 4 and the mounting seat 41 are nested and fixed together. The mounting seat 41 has a through hole at its center and is fixedly connected to the connecting rod sleeve 25. The connecting rod sleeve 25 communicates with the flow measurement chamber 20 through the through hole at the center of the mounting seat 41. When the float connecting rod 23 enters the connecting rod sleeve 25, the cross structure at the end of the float rod can straighten the float connecting rod 23, enabling the float to move in the vertical direction. Additionally, through the cross structure at the end of the float rod, the contact area between the float connecting rod 23 and the inner wall of the connecting rod sleeve 25 can be effectively reduced, thereby reducing the friction between the float connecting rod 23 and the inner wall of the connecting rod sleeve 25 during the up and down movement. At the same time, it can also prevent the generation of negative pressure when there is water and oil in the connecting rod sleeve 25, sucking the float connecting rod 23 and causing the float connecting rod 23 to not fall back into the measurement chamber normally.

[0030] The top of the third housing 3 is connected to the meter head 5. The meter head 5 houses a circuit board with circuit components and is equipped with an antenna for the display screen and the wireless module. Among them, the processing module and its peripheral circuits in this device are all arranged on the circuit board in the meter head 5.

[0031] A gas separation partition 61 is arranged between the first housing 1 and the second housing 2, with multiple ventilation holes distributed thereon. An air inlet is provided on the first housing 1, and this air inlet is located on the first housing 1 between the gas separation partition 61 and the lower surface of the connecting seat 4. An air outlet is provided on the liquid outlet pipeline of the liquid outlet connecting member 12, and the two ends of the gas pipeline 6 are respectively connected to the air inlet and the air outlet through interfaces. Since crude oil is a mixed liquid integrating oil, gas, water, and various other liquid components and solid particles, the gas component therein more or less affects the measurement of the crude oil flow rate. In this embodiment, by arranging the gas separation partition 61 at the upper part of the liquid chamber 10, the gas escaping from the crude oil during the flowing process passes through the gas separation partition 61, gathers above the gas separation partition 61, and is then introduced back into the liquid outlet pipeline of this device through the gas pipeline 6 and flows back to the crude oil transportation pipeline together with the liquid. Thus, the influence of gas on the flow rate measurement is reduced, making the measurement of the flow rate more accurate.

[0032] In this embodiment, a hole is formed in the first housing 1 that constitutes the liquid chamber, and a water content detection device 7 is installed. Its water content sensing end is built into the liquid chamber 10. In one embodiment, the water content detection device 7 has a built-in processor, so as to directly obtain the water content of the liquid in the liquid chamber 10, send the water content to the meter head 5, store it in the memory, or display it on the display screen of the meter head 5, or transmit it wirelessly to a legal device at a distance. In other embodiments, the water content detection device 7 only senses the liquid in the liquid chamber 10 to obtain water content detection data, and sends it to the processing module of the meter head 5, which calculates the water content of the liquid in the liquid chamber 10.

[0033] In this embodiment, a pressure sensor 8 is further connected to the connecting seat 4, and its pressure sensing part is communicated with the liquid chamber 10. The connecting pipe 81 passes through the connecting seat 4 and the gas separation partition 61 and is communicated with the liquid chamber 10, so that the pressure sensor 8 can sense the pressure generated by the crude oil fluid. The signal end of the pressure sensor 8 is connected to the processing module in the meter head 5, and the processing module calculates the current pipeline pressure according to the pressure sensing signal sent by the pressure sensor 8, or receives the pressure value data sent by the pressure sensor 8. The pressure value data is either stored in the memory, or displayed on the display screen, or transmitted wirelessly to a legal device at a distance.

[0034] As Figure 6 shown, it is a principle block diagram of the control device of the crude oil parameter detection device according to this embodiment. The control device in this embodiment includes a processing device for measuring flow rate. The processing device includes a data processing module 90, a position detection module 91, a wireless transmission module 92, and a man-machine interface 93. In this embodiment, the water content detection device 7 and the pressure sensor 8 are respectively connected to the data processing module 90 and send their respective data to the data processing module 90. The position detection module 91 is located in the detection chamber 30. It can detect the rising height of the float in the flow measurement chamber 20 and send the height detection signal to the data processing module 90. The data processing module 90 calculates the crude oil flow rate in the crude oil transmission pipeline according to a preset calculation formula. The wireless transmission module 92 is, for example, a wireless module such as Bluetooth, WiFi, or ZigBee. It can transmit the calculated flow rate data, pressure data, water content data, etc. of the fluid to be measured to a legal device at a distance. Therefore, the staff does not need to go to the measurement site to read the data, and can also receive parameters, instructions, etc. from a legal device at a distance.

[0035] The human-machine interaction interface 93 includes buttons and a display screen. The display screen can display various data. For example, regarding the flow rate option, it can display the instantaneous flow rate, cumulative flow rate, and the condition parameters used for calculating the flow rate. The display screen can also display relevant data regarding the pressure option and the moisture content option. By pressing the corresponding buttons to bring up the corresponding options, the corresponding data will be displayed on the display screen. By cooperating with different buttons, the corresponding parameters can also be modified. For example, various parameters used for calculating the flow rate can be input by authorized staff through the human-machine interaction interface 93, and the said authorization can be confirmed by verifying the set password. Of course, it can also be sent to the data processing module 90 through the wireless transmission module 92. The human-machine interaction interface 93 can of course also be implemented using a touch screen.

[0036] Figure 7 is a schematic structural diagram of a position detection module according to an embodiment of the present invention. In this embodiment, the position detection module 91 is a sensor sleeve, which includes a first sensing sleeve 910 and a plurality of first sensor arrays 911 fixed on the outer surface of its side. As shown in the figure, there are a total of 6 first sensor arrays 911 fixed on the outer surface of the side of the first sensing sleeve 910, arranged in a circular and helically ascending pattern. The first sensing sleeve 910 covers the connecting rod sleeve 25, and its end is fixed together with the connecting seat 4. Each first sensor array 911 includes a plurality of Hall sensors 9100 arranged on a chip board (see Figure 8 ) and a signal socket 912. The chip board is fixed on the first sensing sleeve 910 with the sensors facing inward. The signal sockets 912 on multiple chip boards are connected in series and are connected to the data processing module 90 in the meter head 5.

[0037] The end of the float connecting rod 23 enters the connecting rod sleeve 25 through the connecting seat 4 and moves freely up and down with the fluid to be measured therein. A magnet 913 is fixed at the end of the connecting rod sleeve 25, as Figure 5 shown. When the float connecting rod 23 moves up and down, when the magnet 913 reaches the sensing point of the Hall sensor, it can be sensed by the Hall sensor, thereby generating a height detection signal and sending it to the data processing module 90 in the meter head 5. The magnet 913 in the present invention can use a permanent magnet with strong magnetism, such as neodymium iron boron magnet, samarium cobalt magnet, alnico magnet, etc.

[0038] See Figure 8 which is a schematic diagram after unfolding the six first sensor arrays 911 in Figure 7 . From Figure 8As can be seen, the distance between two adjacent Hall sensor sensing points in each first sensor array 911 is d = D. By means of another five first sensor arrays 911 arranged in a spiral ascending manner, the sensing distance D in one first sensor array 911 is evenly divided into six parts, that is, the sensing distance d between two adjacent Hall sensors in the current Hall sensor array is d = D / 6. Therefore, the detection accuracy of the sensor array in this embodiment is increased by 6 times compared with that of only one first sensor array 911. By setting the distance D between two adjacent Hall sensors in one first sensor array 911 and the number of first sensor arrays 911, different-precision sensing distances can be obtained. The precision of the sensing distance corresponds to the measurement precision of the rising height of the float. The sensing total height h is formed from the sensing point of the lowest-position sensor to the sensing point of the highest-position sensor T , that is, it corresponds to the range of the flow measurement of this device, and the corresponding sensing total height h can be set according to the actual measurement range in the application scenario T .

[0039] In this embodiment, each sensor has a unique position information. For example, four-digit numbers are used to represent the position information of a sensor. Among them, the first two numbers represent the number of the first sensor array, and the last two numbers represent the position number arranged vertically in the first sensor array. For example, the position information 0210 indicates that the sensor is the 10th sensor in the second first sensor array

[0040] See Figure 9 , which is a schematic diagram of the calculation principle of the crude oil parameter detection device when the float is a floating ball. It is a partial schematic diagram of the axial section of the conical tube. The float moves upward under the action of the fluid to be measured. When the float is in force balance in the measuring tube, it stabilizes at a height, and the height of the float stop at this time is Δh. The volume flow calculation formula 1-1 of the crude oil parameter detection device is

[0041]

[0042] q v is the volume flow, α is the flow coefficient of this device, ε is the gas expansion coefficient when the fluid to be measured is a gas (this invention is used for crude oil metering, and crude oil is an incompressible fluid, ε = 1), g is the acceleration of gravity, V f is the volume of the float or floating ball, ρ f is the density of the float material, ρ is the density of the fluid to be measured, F f is the cross-sectional area at the maximum working position of the float, ΔF is the flow-through annular area, θ is the cone angle of the measuring tube, and Δh is the height of the float from its lowest position to the current measurement position

[0043] When the float is a sphere, R fR is the radius of the floating ball, and Rp is the working radius of the measuring tube corresponding to the location of the floating ball.

[0044] Among them, Rp = (R f +Δhsin(θ / 2)) 1-2

[0045] ΔF = πRp 2 -F f 1-3

[0046] F f =πR f 2 1-4

[0047] Substitute the above three formulas into Formula 1-1 to obtain the following Formula 1-5:

[0048]

[0049] In Formula 1-5, except for the height Δh of the float from its lowest position to the current measurement position, other parameters are known parameters. When the height value Δh of the float rising is obtained, the instantaneous flow rate of the measured crude oil fluid can be calculated through Formula 1-5, and the cumulative flow rate for a period of time can be obtained through the following Formula 1-6.

[0050]

[0051] Among them, Q t represents the cumulative flow rate at time t, Q0 represents the cumulative flow rate at t = 0, q t represents the instantaneous flow rate at time t, and t represents time (unit: s).

[0052] In addition to the spherical shape, the float in the present invention can also be any structure with a circular working cross-section and symmetric along the vertical center line, such as a cylinder, a cone, an ellipsoid, a sphere, etc., or a structure obtained by combining the above various shapes, which can make the force conditions on all sides of the float uniform, so that it can move up and down stably in the measured original fluid. In this embodiment, the float described is Figure 1 the sphere in, and the contact between the floating ball and the inner wall of the conical tube 21 is a line contact. Compared with other shapes, first, the friction generated when the floating ball contacts the inner wall of the measuring tube can be ignored, thus simplifying the force condition of the floating ball, making the calculation process more accurate, and improving the measurement accuracy. Second, when the measured fluid is a liquid with a certain viscosity such as crude oil, the curved surface of the float is beneficial to reducing the resistance of the viscous liquid to the up and down movement of the float in the liquid.

[0053] Such as Figure 10As shown, it is a schematic diagram of the calculation principle of the crude oil parameter detection device when the float is gyro-shaped. When the float is gyro-shaped, when it is impacted by a large flow of fluid, it reduces the lateral sway through its own rotation, so that it can move up and down stably in the vertical direction. Figure 10 It is a partial schematic diagram of the axial section of the conical tube. The volume flow formula of the crude oil parameter detection device is as shown in Formula 1-1:

[0054]

[0055] q v is the volume flow, α is the flow coefficient of the flowmeter, ε is the gas expansion coefficient when the measured fluid is a gas (in this invention, it is used for crude oil metering, and crude oil is an incompressible fluid, so ε = 1), g is the acceleration due to gravity, Vf is the volume of the float, ρ f is the density of the float material, ρ is the density of the measured fluid, F f is the maximum cross-sectional area of the float, ΔF is the flow-through annular area, θ is the cone angle of the measuring tube, Δh is the height of the float from its lowest position to the current measurement position, Rp is the working radius of the measuring tube corresponding to the position of the float, and Rf is the working radius of the float.

[0056] Among them, Rp = (Rf + Δhtan(θ / 2)) 1-7

[0057] ΔF = πRp 2 -F f 1-3

[0058] F f =πR f 2 1-4

[0059] Substitute the above three formulas into Formula 1-1 to obtain the following Formula 1-8:

[0060]

[0061] In Formula 1-8, except for the height Δh of the float from its lowest position to the current measurement position, other parameters are known parameters. When the height value Δh of the float rising is obtained, the instantaneous flow rate of the measured fluid can be calculated through Formula 1-8, and the cumulative flow rate for a period of time can be obtained through Formula 1-6 above.

[0062] When the data processing module 90 receives the signal sent by the sensor array, it can determine the sensor position according to the position information, and then query the internal correspondence table between the sensor and the height to obtain the height value, that is, the rising height value Δh of the float in the measurement chamber. When the current device uses a floating ball as the float, the data processing module 90 calculates the instantaneous flow rate using Equation 1-5. When the current device uses a gyro-shaped float, it calculates the instantaneous flow rate using Equation 1-8 and calculates the cumulative flow rate using Equation 1-6, so as to obtain the flow rate data of the measured oil transmission pipeline.

[0063] Figure 11 is the external structure diagram of another crude oil parameter detection device, and its structure is similar to that of Figure 1 shown in the embodiment, the difference is that Figure 11 the liquid chamber in Figure 11 The exploded view of the crude oil parameter detection device shown in Figure 12 is shown as follows. It can be seen that the position detection module 91 is a sensor sleeve, which is the same as Figure 1 and will not be elaborated here.

[0064] The connecting piece for connecting the detection chamber 30, the liquid chamber 10 and the flow measurement chamber 20 in the foregoing embodiment is the connecting seat 4 and the internal mounting seat 41. In another connection method, a flange connection method as shown in Figure 13 can also be adopted. Among them, the connecting piece includes an upper flange 43 and a lower flange 44. The first housing 1 is connected to the lower part of the lower flange 44, the second housing 2 is fixed to the lower part of the lower flange 44 through the mounting seat. Through holes are provided in the centers of the upper flange 43 and the lower flange 44 to allow the float connecting rod 23 to pass through. The third housing 3 is connected to the upper part of the upper flange 43, and the sensor sleeve serving as the position detection module 91 is fixed on the upper flange 43.

[0065] In Figure 13 the embodiment shown, compared with the device structure shown in Figure 1 and Figure 11 this embodiment does not have a gas separation structure, a moisture content detection device and a pressure sensor. Therefore, the processing module in the meter head of this embodiment only needs to calculate the flow rate data, display or transmit the flow rate data to the remote end. Of course, according to application requirements, a moisture content detection device and a pressure sensor can be added to the structure shown in Figure 13 . In addition, regarding the gas separation structure, since the crude oil components produced by different oil wells are different, more gas will affect the accuracy of flow measurement. Therefore, gas separation is required before measuring the flow rate. At this time, a device with a gas separation structure as shown in Figure 1 and Figure 11 can be used, or other gas separation devices can be separately provided in the conveying pipeline. Figure 13The structure shown is connected in the conveying pipeline equipped with a gas separation device. Since gas separation has been carried out when the liquid flows through this device, there is no need to set up a gas separation structure in this device. In addition, there is not much gas in the oil produced from some oil wells. At this time, gas separation is not required, so the device shown in Figure 13 can be connected in the conveying pipeline to measure the flow rate.

[0066] The position detection module in each of the foregoing embodiments uses a Hall sensor array. Of course, other sensors or position detection methods can also be used. For example, the present invention can also detect the rising position of the float through an image acquisition device or a photoelectric sensor arranged in the detection cavity in cooperation with a scale.

[0067] As Figure 14A shown, a bracket 126a is arranged outside the connecting rod sleeve 125a, a slideway 127a is arranged therein, a moving block 129a is arranged at a position corresponding to the magnet 123a, and the moving block 129a is connected to a scale 128a. In one embodiment, the moving block 129a is an iron block. When the float rises in the measuring tube, the magnet 123a at its end rises, which attracts the moving block 129a to rise together, and the scale 128a connected to the moving block 129a rises simultaneously. An image acquisition device 130a, such as a camera, is installed on the housing 41a at the end of the connecting rod sleeve 125a. The scale of the scale 128a is marked from the top to the bottom. That is, when the float is at the bottommost position, the position corresponding to the topmost of the scale 128a and the image acquisition device 130a is the starting position 0, starting from 0 and going down until the position of the moving block 129a is the maximum scale. When the float rises, the magnet 123a at its end attracts the moving block 129a to drive the scale 128a to rise, and the image acquisition device 130a acquires the current scale image. The rising height of the float can be obtained through image recognition by the processing module.

[0068] As Figure 14B shown, in this embodiment, the scale 128b is fixed to the bracket 126b, and the starting position of the scale 128b is at the lowermost moving block 129b. And its scale is represented by depth. A photoelectric sensor is arranged on the moving block 129b. When the moving block 129b rises along the slideway 127b with the magnet 123a, the light emitted by the light emitter of the photoelectric sensor shines on the scale 128b, and the light receiver receives the light reflected from the scale 128b. The current scale of the scale 128b is determined according to the change in the light energy of the received light signal.

[0069] Alternatively, other methods can also be used to achieve the tracking movement of the moving blocks and magnets 123a and 123b. For example, Hall sensors and linear motors are provided on the moving blocks 129a and 129b. When the Hall sensors sense the magnets 123a and 123b, the linear motors drive the scale 128a or the photoelectric sensor to move following the magnets 123a and 123b.

[0070] As Figure 14C shown, in this embodiment, a sensor sleeve 40c is provided, which is sleeved outside the brackets 126c, the slideways 127c and the moving blocks 129c. In some other embodiments, without a scale, a plurality of photoelectric sensors are provided on the sensor sleeve 40c to form a sensor array. The cross-section of the sensor sleeve 40c is as Figure 15A shown. The sensor array is composed of a plurality of photoelectric sensors 212c vertically arranged on the inner surface of the side of the sensor sleeve 40c. Each photoelectric sensor 212c at each horizontal position includes a light emitting part 2121c and a light receiving part 2122c, and the two are fixed on the sensor sleeve 40c. Among them, the path 2123c formed by the light emitting part 2121c and the light receiving part 2122c intersects with the vertical movement path of the moving block 129c up and down. The float connecting rod telescopically moves in the second sensing sleeve 125c, driving the moving block 129c in the sensor sleeve 40c to move on the slideway 127c. When it blocks the path 2123c formed by the light emitting part 2121c and the light receiving part 2122c of a photoelectric sensor, the photoelectric sensor sends a signal. According to the position of the photoelectric sensor that sends the signal, the position of the float connecting rod can be determined, and thus the rising height of the float from the lowest position to the detection position can be obtained.

[0071] In another embodiment, as Figure 15B shown, the sensor array on the sensor sleeve 40d is composed of the light receiving parts 2122d of a plurality of photoelectric sensors. The light receiving parts 2122d are installed on the inner wall of the sensing sleeve 40d, and the light emitting parts 2121d are installed on the moving block 129d. The light emitting parts 2121d always emit light. When the moving block 129d moves on the slideway 127d, the light emitted by the light emitting parts 2121d can be received by the light receiving parts 2122d at different heights and an electrical signal is sent out. The processing module can determine the position of the float connecting rod according to the position of the photoelectric sensor that sends the electrical signal.

[0072] A corresponding relationship table between the sensor position and the height is stored in the processing module. The processing module queries this corresponding relationship table according to the sensor position to obtain the rising height of the float, and thus the flow rate of the measured petroleum can be calculated. The specific process can refer to the embodiment using the Hall sensor as the sensor array and will not be elaborated here.

[0073] The above position detection module and the corresponding structure only disclose relevant position detection means. Those of ordinary skill in the art can choose any one of the above detection means according to actual needs, or obtain relevant position detection structures inspired by the above detection means.

[0074] In summary, the detection device provided by the present invention can be directly connected to the crude oil pipeline. It is small in size, occupies little space, and is convenient for installation and daily maintenance. This device can measure the flow rate in the crude oil pipeline. Since it does not require the transmission device in the traditional float flowmeter, it will not affect the measurement accuracy due to the fatigue damage of the transmission device during long-term use. And it can integrate other parameter detection devices according to the actual application requirements, so as to be able to detect multiple data. The structure of the device is strong and durable, and it can work stably for a long time in various field environments.

[0075] The above embodiments are only for illustrating the present invention, rather than limiting the present invention. Those of ordinary skill in the relevant technical field can make various changes and modifications without departing from the scope of the present invention. Therefore, all equivalent technical solutions should also fall within the scope of the disclosure of the present invention.

Claims

1. An apparatus for detecting crude oil parameters, comprising: A liquid chamber, which is formed by a first housing and includes a first liquid inlet and a first liquid outlet; A flow measurement chamber, which is formed by a second housing and is built in the liquid chamber. It includes a second liquid inlet and a second liquid outlet, and the second liquid outlet is communicated with the first liquid outlet through a liquid outlet pipe; A float assembly, which is built in the flow measurement chamber and includes a float and a float connecting rod integrally connected thereto. The end of the float connecting rod is connected to a detection part; A detection chamber, which is formed by a third housing and internally includes at least a position detection module; A connecting member, whose upper part is fixed to the third housing forming the detection chamber, and whose lower part is respectively connected to the first housing forming the liquid chamber and the second housing forming the flow measurement chamber. And a through hole is provided on the connecting member, and the end of the float connecting rod can extend into the detection chamber through the through hole; And A processing module, which is configured to be at least connected to the position detection module. When the detection part at the end of the float connecting rod extends into the detection chamber, the position detection module obtains a float height detection signal by detecting the position of the detection part at the end of the float connecting rod; the processing module calculates the flow rate of the measured crude oil according to the float height detection signal.

2. The apparatus for detecting crude oil parameters according to claim 1, wherein pipeline connectors are respectively connected to the first liquid inlet and the first liquid outlet for connecting to a crude oil transportation pipeline.

3. The apparatus for detecting crude oil parameters according to claim 1, wherein the centers of the first liquid inlet and the first liquid outlet are located on the same cross-section of the liquid chamber.

4. The apparatus for detecting crude oil parameters according to claim 1, wherein the second liquid inlet is opened at the bottom of the flow measurement chamber, and the second liquid outlet is opened at the side of the flow measurement chamber.

5. The apparatus for detecting crude oil parameters according to claim 1, wherein the float is a structure with a circular working cross-section and symmetric along the vertical center line.

6. The apparatus for detecting crude oil parameters according to claim 1, further comprising: A connecting rod sleeve, which is arranged in the detection chamber, fixed to the upper part of the connecting member, and communicated with the through hole on the connecting member; And A float stabilizing structure, which is connected to the end of the float connecting rod and includes a cylinder and a plurality of side edges protruding from the side surface of the cylinder along the axial direction of the cylinder; Wherein, when the float rises, the end of the float connecting rod and the float stabilizing structure extend into the connecting rod sleeve.

7. The apparatus for detecting crude oil parameters according to claim 1, further comprising: A gas separation partition, which is built in the liquid chamber, placed between the second housing and the first housing, and has a plurality of air permeable holes distributed thereon; An air inlet, which is opened on the first housing between the gas separation partition and the lower surface of the connecting member; An air outlet, which is opened on the liquid outlet pipe located outside the liquid chamber; and A gas pipe, whose two ends are respectively connected to the air inlet and the air outlet through interfaces.

8. The crude oil parameter detection device according to claim 1, further comprising a pressure sensor configured to be installed on the upper part of the connecting member, and its pressure sensing part penetrates through the connecting member and communicates with the liquid chamber; its signal end is connected to the processing module, and the processing module calculates the current pipeline pressure according to the pressure sensing signal sent by the pressure sensor, or receives the pressure value data sent by the pressure sensor.

9. The crude oil parameter detection device according to claim 1, further comprising a water content detection device, whose connecting seat is installed on the first housing forming the liquid chamber, its water content sensing end is built in the liquid chamber, and its signal end is connected to the processing module. The processing module calculates the current water content according to the water content sensing signal sent by the water content detection device, or receives the water content data sent by the water content detection device.

10. The crude oil parameter detection device according to claim 1, wherein the position detection module is a sensor array. When the detection part at the end of the float connecting rod moves vertically up and down in the detection chamber, the sensors in the sensor array output a float height detection signal when detecting the detection part.

11. The crude oil parameter detection device according to claim 10, wherein the sensor array is composed of a plurality of Hall sensors, and the plurality of Hall sensors are arranged in a first sensor array along the vertical moving direction of the float connecting rod; the plurality of first sensor arrays are arranged in a spiral ascending manner along the vertical moving direction of the float connecting rod on the outer surface of the side of the first sensing sleeve; the detection part at the end of the float connecting rod is a magnet.

12. The crude oil parameter detection device according to claim 10, wherein the sensor array is composed of a plurality of photoelectric sensors arranged on the inner surface of the side of the second sensing sleeve.

13. The crude oil parameter detection device according to any one of claims 10-12, wherein the detection signal output by the sensor array includes position information and data information, and the position information includes the position of the sensor that emits the data information in the sensor array.

14. The crude oil parameter detection device according to claim 1, wherein the position detection module includes an image acquisition device or a photoelectric sensor arranged in the detection chamber, and a scale.

15. The crude oil parameter detection device according to claim 1 or 8 or 9, wherein a meter head is installed on the third housing and communicates with the third housing, and the processing module is located in the meter head.

16. The crude oil parameter detection device according to claim 15, wherein the meter head includes: a human-computer interaction interface, which is connected to the processing module and is configured to display data and input data; and / or a wireless transmission module, which is connected to the processing module and is configured to send the obtained detection data to a legal device at a remote end, and / or receive data from a legal device at a remote end.

Images