CN110849429A - Oil gas recovery ultrasonic flowmeter - Google Patents
Oil gas recovery ultrasonic flowmeter Download PDFInfo
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- CN110849429A CN110849429A CN201910864098.8A CN201910864098A CN110849429A CN 110849429 A CN110849429 A CN 110849429A CN 201910864098 A CN201910864098 A CN 201910864098A CN 110849429 A CN110849429 A CN 110849429A
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- ultrasonic transducer
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
- G01F1/662—Constructional details
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F15/00—Details of, or accessories for, apparatus of groups G01F1/00 - G01F13/00 insofar as such details or appliances are not adapted to particular types of such apparatus
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- Fluid Mechanics (AREA)
- General Physics & Mathematics (AREA)
- Electromagnetism (AREA)
- Measuring Volume Flow (AREA)
Abstract
The invention discloses an oil gas recovery ultrasonic flowmeter, which comprises a main body and is characterized in that: a through flow channel is formed in the middle of the main body, a first measuring flow channel and a second measuring flow channel which are intersected with the flow channel are formed in two sides of the flow channel, and the axes of the first measuring flow channel and the second measuring flow channel are on the same straight line; and a first ultrasonic transducer is arranged on the first measuring flow channel, and a second ultrasonic transducer is arranged on the second measuring flow channel. First ultrasonic transducer, second ultrasonic transducer have the mainboard through cable junction, the mainboard is used for controlling first ultrasonic transducer, second ultrasonic transducer and mutual information transfer through the cable. By the arrangement of the device, the low-speed or high-speed detection precision of the gas is improved, the detection precision is not influenced by the change of a gas medium and the change of temperature, and the safety of combustible gas detection is improved; and no mechanical vibration exists, and the system is safe and reliable.
Description
Technical Field
The invention relates to the field of flow measurement, in particular to an oil gas recovery ultrasonic flowmeter.
Background
With the development of cities and industries, the demands of people on gas, natural gas, industrial gas and the like are increased day by day, and the measurement technology of gas flow measurement is more and more emphasized by people. The flowmeter capable of measuring various gases more accurately, conveniently and stably is important. The existing flowmeter has the problems of complex structure and inaccurate measurement.
Disclosure of Invention
The invention aims to: to the problems existing in the prior art, the oil gas recovery ultrasonic flowmeter is provided, the problem of gas metering recovery during volatile oil gas recovery is solved, and the problem of safety of measurement during combustible gas recovery is solved.
The utility model provides an oil gas recovery ultrasonic flowmeter, includes the main part, its characterized in that: a through flow channel is formed in the middle of the main body, a first measuring flow channel and a second measuring flow channel which are intersected with the flow channel are formed in two sides of the flow channel, and the axes of the first measuring flow channel and the second measuring flow channel are on the same straight line; and a first ultrasonic transducer is arranged on the first measuring flow channel, and a second ultrasonic transducer is arranged on the second measuring flow channel.
Further, the invention discloses a preferable structure of the oil gas recovery ultrasonic flowmeter, wherein the first ultrasonic transducer and the second ultrasonic transducer are connected with a main board through cables, and the main board is used for controlling the first ultrasonic transducer, the second ultrasonic transducer and mutual information transmission through the cables.
Further, the included angle between the axis of the first measuring flow channel and the axis of the second measuring flow channel and the axis of the flow channel is 45 degrees.
Furthermore, a first ultrasonic transducer pressing ring is arranged in the first measuring flow channel, the first ultrasonic transducer pressing ring fixes the first ultrasonic transducer in the first measuring flow channel, and a first ultrasonic transducer plug is arranged at the tail end of the first measuring flow channel; the first ultrasonic transducer plug is used for sealing the first measuring flow channel and fixing the first ultrasonic transducer compression ring.
Furthermore, a second ultrasonic transducer pressing ring is arranged in the second measuring flow channel, the second ultrasonic transducer pressing ring fixes the second ultrasonic transducer in the second measuring flow channel, and a second ultrasonic transducer plug is arranged at the tail end of the second measuring flow channel; and the second ultrasonic transducer plug is used for sealing the second measuring flow channel and fixing the second ultrasonic transducer compression ring. And the distance between the first ultrasonic transducer and the second ultrasonic transducer is ensured to be fixed and unchanged.
Furthermore, a main board accommodating cavity is formed in the main body, an overhaul opening is formed in the main board accommodating cavity, and the overhaul opening is detachably connected with an upper cover; the main board is connected with a cable; the cable passes through the main board accommodating cavity and is connected with the outside. The main board transmits energy and information with the outside through a cable, and the upper end of the main board is provided with an upper cover which is integrally sealed with the main body; the flow channel comprises an air inlet and an air outlet, and the calibers of the air inlet and the air outlet are phi 12 ferrule connectors.
Furthermore, the mainboard comprises a processor, a time-to-digital converter, a storage circuit, a communication circuit and a power supply circuit; the processor is electrically connected with the communication circuit, the storage circuit, the power supply circuit and the time-to-digital converter; the time-to-digital converter is in signal connection with the processor, the first ultrasonic transducer and the second ultrasonic transducer. The communication circuit comprises a pulse communication interface circuit and an RS485 communication interface circuit; the power supply circuit comprises a power supply interface and an intrinsic safety processing circuit, and the power supply interface is connected with the load end of the mainboard through the intrinsic safety processing circuit.
Further, the diameter of the flow channel is 8-11 mm.
A measuring method of an oil gas recovery ultrasonic flowmeter comprises the following steps:
1. the processor sends a measurement instruction to the time-to-digital converter, and the time-to-digital converter automatically controls the first ultrasonic transducer and the second ultrasonic transducer to alternately send and receive ultrasonic signals after receiving the instruction;
2. the first ultrasonic transducer is in a transmitting state, the second ultrasonic transducer is in a receiving state, and then the propagation time T of the downstream flow of the ultrasonic pulse in the measured medium is measureds；
3. The second ultrasonic transducer 12 is in a transmitting state, the first ultrasonic transducer 8 is in a receiving state, and then the propagation time T of the pulse in the medium to be measured in the reverse flow is measuredn；
4. The processor obtains T according to the measurements、TnThe flow rate of the gas is calculated.
The step 4 comprises the following steps:
combining the two formulas (1) and (2) to obtain the fluid flow velocity V:
as can be seen from the calculation of the formula (3), when the flow rate of the fluid is measured, only the accurate timing system needs to be used for TsAnd TnSampling is performed without obtaining the propagation velocity of the ultrasonic wave.
The actual flow velocity of the fluid has a flow velocity distribution on the section of the pipeline, relative to the flow velocity distribution on the central lineThe flow velocity V measured by the formula (3) is a linear average velocity on the diameter of the cross section of the pipe, and the surface average flow velocity V of the inner cross section of the pipe is required for measuring the flowmV and VmThere is a fluid correction factor K, by which the flow Q through the pipe can be calculated:
wherein:
Ts-ultrasonic downstream transit time in seconds(s);
Tn-ultrasonic counter-current propagation time in seconds(s);
l- -ultrasonic transmission distance in meters (m);
c- - -the propagation velocity of the ultrasonic waves in the fluid, in meters per second (m/s);
v- - -the flow velocity of the measured medium in meters per second (m/s);
theta < - > -the included angle between the flowing direction of the measured medium and the propagation direction of the ultrasonic waves, and the unit is Degree (DEG);
k, correcting the error of the pipeline flow correction coefficient;
q- - -pipe flow in cubic meters per second (m 3/s);
d- -the inside diameter of the pipe in meters (m). .
The technical scheme adopted by the invention is as follows: .
In summary, due to the adoption of the technical scheme, the invention has the beneficial effects that:
1. by the arrangement of the device, the low-speed or high-speed detection precision of the gas is improved, the detection precision is not influenced by the change of a gas medium and the change of temperature, and the safety of combustible gas detection is improved; and no mechanical vibration exists, and the system is safe and reliable.
2. The time measurement is more accurate through the accurate time difference measurement, so that higher measurement accuracy is obtained.
3. By adopting the intrinsic safety type design, an explosion-proof hose is not needed, the wiring is simple, and the installation and maintenance cost is low.
Drawings
The invention will now be described, by way of example, with reference to the accompanying drawings, in which:
FIG. 1 is a schematic structural view of the present invention;
FIG. 2 is a block diagram of the circuit configuration of the present invention;
the labels in the figure are: the structure comprises a main board 1, a cable 2, a flow channel 3, an air inlet 4, a main body 5, a first ultrasonic transducer plug 6, a first ultrasonic transducer compression ring 7, a first ultrasonic transducer 8, an air outlet 9, a second ultrasonic transducer plug 10, a second ultrasonic transducer compression ring 11, a second ultrasonic transducer 12 and an upper cover 13.
Detailed Description
All of the features disclosed in this specification, or all of the steps in any method or process so disclosed, may be combined in any combination, except combinations where mutually exclusive features and/or steps are present.
Any feature disclosed in this specification (including any accompanying claims, abstract) may be replaced by alternative features serving equivalent or similar purposes, unless expressly stated otherwise. That is, unless expressly stated otherwise, each feature is only an example of a generic series of equivalent or similar features.
Example 1:
as shown in fig. 1 and 2, the present invention includes a flow passage 3, and a main body 5 is provided outside the flow passage 3. A measuring flow channel intersected with the flow channel 3 is arranged on the main body 5; in the measuring flow channel, a first ultrasonic transducer 8 and a second ultrasonic transducer 12 are oppositely arranged at two ends of the flow channel 3, a main board 1 is installed in the main body 5, and the first ultrasonic transducer 8 and the second ultrasonic transducer 12 are connected with the main board 5 through leads. The flow passage 3 and the main body 5 are made of flame-retardant plastic or metal for improving the explosion-proof performance. The first ultrasonic transducer 8 and the second ultrasonic transducer 12 may receive or transmit ultrasonic waves, and may convert the received ultrasonic waves into electrical signals and transmit the electrical signals, or transmit corresponding ultrasonic waves according to the received electrical signals.
The main body 5 is internally provided with a measuring flow channel, the diameter of the measuring flow channel is 8-10mm, and the included angle between the axis of the measuring flow channel and the axis of the flow channel 3 is 45 degrees. The through flow channel 3 enables the flow velocity of the fluid to be uniform without pressure loss, and improves the stability of the flow field.
The main board 1 includes a processor, a time-to-digital converter, a storage circuit, a communication circuit, and a power supply circuit. The processor is connected with the communication circuit, the storage circuit, the power supply circuit and the time-to-digital converter. The time-to-digital converter is connected to the processor, the first ultrasonic transducer 8 and the second ultrasonic transducer 12.
When the gas purifier is used specifically, the equipment is installed on a gas circulation pipeline, and the equipment is connected with a power supply and a receiver.
In the specific operation process, the processor generates a measurement instruction to the time-to-digital converter, and the time-to-digital converter receives the instruction. First, the first ultrasonic transducer 8 is controlled to be in a transmitting state, the second ultrasonic transducer 12 is controlled to be in a receiving state, and the downstream propagation time is recorded as Ts. Then automatically controlling the second ultrasonic transducer 12 to be in a transmitting state, controlling the first ultrasonic transducer 8 to be in a receiving state, and recording the propagation time of the down-flow as Tn。
Then according to TsAnd TnThe time difference and the change in the acoustic velocity caused by the gas flow velocity can calculate the gas flow velocity.
The flow rate can then be calculated as follows:
combining the two formulas (1) and (2) to obtain the fluid flow velocity V:
calculated by the formula (3)When measuring the flow rate of the fluid, only the accurate timing system is needed to be used for TsAnd TnSampling is performed without obtaining the propagation velocity of the ultrasonic wave.
The actual fluid flow velocity has a flow velocity distribution on the cross section of the pipe, and the flow velocity V measured by equation (3) is the linear average velocity on the diameter of the cross section of the pipe relative to the single-channel ultrasonic flow meter on the center line, and the surface average flow velocity V of the cross section in the pipe is required for measuring the flowmV and VmThere is a fluid correction factor K, by which the flow Q through the pipe can be calculated:
Ts-ultrasonic downstream transit time in seconds(s);
Tn-ultrasonic counter-current propagation time in seconds(s);
l- -ultrasonic transmission distance in meters (m);
c- - -the propagation velocity of the ultrasonic waves in the fluid, in meters per second (m/s);
v- - -the flow velocity of the measured medium in meters per second (m/s);
theta < - > -the included angle between the flowing direction of the measured medium and the propagation direction of the ultrasonic waves, and the unit is Degree (DEG);
k, correcting the error of the pipeline flow correction coefficient;
q- -pipe flow in cubic meters per second (m)3/s)；
D- -the inside diameter of the pipe in meters (m).
Example 2:
on the basis of the above embodiments, a preferred embodiment of an oil and gas recovery ultrasonic flowmeter is disclosed.
The communication circuit comprises a pulse communication interface circuit and an RS485 communication interface circuit; the power supply circuit comprises a power supply interface and an intrinsic safety processing circuit, and the power supply interface is electrically connected with a load of the mainboard 1 through the intrinsic safety processing circuit. By adopting the pulse communication interface circuit, the communication broadband and the communication efficiency can be improved, the sampling rate is further improved, and the measurement precision is improved.
Example 3:
on the basis of embodiment 2, a preferred implementation mode of the oil gas recovery ultrasonic flowmeter is disclosed.
The main body 5 is connected with a cable 2, and the main board 1 is communicated with the outside through the cable 2; the flow channel 3 comprises an air inlet 4 and an air outlet 9, and the calibers of the air inlet 4 and the air outlet 9 are phi 12 ferrule interfaces. The implementation mode adopts a phi 12 ferrule interface. The air inlet 4 and the air outlet 9 are connected with the pipeline by adopting threaded joints.
The main board 1 meets the requirement of the anti-explosion design of GB 3836. The protection level of the body 5 reaches the IP65 level.
Example 4:
as shown in fig. 1, the flow channel 3 is cylindrical with a diameter of 8-11mm, and the circular channels for mounting the first ultrasonic transducer 8 and the second ultrasonic transducer 12 intersect the flow channel 3 at an angle of 45 °. Under the action of the fluid dynamics, the airflow flowing through the flow channel 3 can not generate flow speed difference and turbulent flow due to the viscosity of the pipe wall, and the flow speed of the gas in the whole cross section is uniform. Therefore, the uniformity of the airflow of the measuring channel can be guaranteed to the maximum extent, and the measuring accuracy is guaranteed.
Implementation 5:
on the basis of embodiment 1, a preferred implementation mode of the oil gas recovery ultrasonic flowmeter is disclosed.
The power supply circuit comprises a power supply interface and an intrinsic safety processing circuit, and the power supply interface is connected with the load end of the mainboard 1 through the intrinsic safety processing circuit. The flow passage 3 and the main body 5 are made of flame retardant plastic or metal for improving the explosion-proof performance thereof.
Example 6:
a measuring method of an oil gas recovery ultrasonic flowmeter comprises the following steps:
combining the two formulas (1) and (2) to obtain the fluid flow velocity V:
as can be seen from the calculation of the formula (3), when the flow rate of the fluid is measured, only accurate timing needs to be performed
The actual fluid flow velocity has a flow velocity distribution on the cross section of the pipe, and the flow velocity V measured by equation (3) is the linear average velocity on the diameter of the cross section of the pipe relative to the single-channel ultrasonic flow meter on the center line, and the surface average flow velocity V of the cross section in the pipe is required for measuring the flowmV and VmThere is a fluid correction factor K, by which the flow Q through the pipe can be calculated:
Ts-ultrasonic downstream transit time in seconds(s);
Tn-ultrasonic counter-current propagation time in seconds(s);
l- -ultrasonic transmission distance in meters (m);
c- - -the propagation velocity of the ultrasonic waves in the fluid, in meters per second (m/s);
v- - -the flow velocity of the measured medium in meters per second (m/s);
theta < - > -the included angle between the flowing direction of the measured medium and the propagation direction of the ultrasonic waves, and the unit is Degree (DEG);
k, correcting the error of the pipeline flow correction coefficient;
q- -pipe flow in cubic meters per second (m)3/s)；
D- -the inside diameter of the pipe in meters (m).
The invention is not limited to the foregoing embodiments. The invention extends to any novel feature or any novel combination of features disclosed in this specification and any novel method or process steps or any novel combination of features disclosed.
Claims (10)
1. An oil gas recovery ultrasonic flowmeter, includes main part (5), its characterized in that: a through flow channel (3) is formed in the middle of the main body (5), a first measuring flow channel and a second measuring flow channel which are intersected with the flow channel (3) are formed in two sides of the flow channel (3), and the axes of the first measuring flow channel and the second measuring flow channel are on the same straight line; and a first ultrasonic transducer (8) is arranged on the first measuring flow channel, and a second ultrasonic transducer (12) is arranged on the second measuring flow channel.
2. The oil and gas recovery ultrasonic flow meter of claim 1, wherein: first ultrasonic transducer (8), second ultrasonic transducer (12) have mainboard (1) through cable junction, mainboard (1) is used for controlling first ultrasonic transducer (8), second ultrasonic transducer (12) and the information transfer between each other through the cable.
3. The oil and gas recovery ultrasonic flow meter according to claim 1 or 2, wherein: the included angle between the axial lines of the first measuring flow channel and the second measuring flow channel and the axial line of the flow channel (3) is 45 degrees.
4. The oil and gas recovery ultrasonic flow meter of claim 3, wherein: a first ultrasonic transducer pressing ring (7) is arranged in the first measuring flow channel, a first ultrasonic transducer (8) is fixed in the first measuring flow channel by the first ultrasonic transducer pressing ring (7), and a first ultrasonic transducer plug (6) is arranged at the tail end of the first measuring flow channel; the first ultrasonic transducer plug (6) is used for sealing the first measuring flow channel and fixing the first ultrasonic transducer compression ring (7).
5. The oil and gas recovery ultrasonic flow meter of claim 4, wherein: a second ultrasonic transducer pressing ring (11) is arranged in the second measuring flow channel, a second ultrasonic transducer (12) is fixed in the second measuring flow channel by the second ultrasonic transducer pressing ring (11), and a second ultrasonic transducer plug (10) is arranged at the tail end of the second measuring flow channel; the second ultrasonic transducer plug (10) is used for sealing the second measuring flow channel and fixing the second ultrasonic transducer compression ring (11).
6. The oil and gas recovery ultrasonic flow meter of claim 5, wherein: a main board accommodating cavity is formed in the main body (5), an overhaul opening is formed in the main board accommodating cavity, and the overhaul opening is detachably connected with an upper cover (13); the main board (1) is connected with a cable (2); the cable (2) penetrates through the main board accommodating cavity to be connected with the outside.
7. The oil and gas recovery ultrasonic flow meter of claim 6, wherein: the mainboard (1) comprises a processor, a time-to-digital converter, a storage circuit, a communication circuit and a power circuit; the processor is electrically connected with the communication circuit, the storage circuit, the power circuit and the time-to-digital converter; the time-to-digital converter is in signal connection with the processor, the first ultrasonic transducer (8) and the second ultrasonic transducer (12).
8. The oil and gas recovery ultrasonic flow meter of claim 7, wherein: the diameter of the flow channel (3) is 8-11 mm.
9. The method of claim 8, comprising the steps of:
1. the processor sends a measurement instruction to the time-to-digital converter, and the time-to-digital converter automatically controls the first ultrasonic transducer (8) and the second ultrasonic transducer (12) to alternately send and receive ultrasonic signals after receiving the instruction;
2. the first ultrasonic transducer (8) is in a transmitting state, the second ultrasonic transducer (12) is in a receiving state, and then the propagation time T of the downstream ultrasonic pulse in the measured medium is measureds；
3. The second ultrasonic transducer 12 is in a transmitting state, the first ultrasonic transducer 8 is in a receiving state, and then the propagation time T of the pulse in the medium to be measured in the reverse flow is measuredn；
4. The processor obtains T according to the measurements、TnThe flow rate of the gas is calculated.
10. The method of claim 9, wherein step 4 comprises the steps of:
the flow rate can be calculated by the following method:
combining the two formulas (1) and (2) to obtain the fluid flow velocity V:
wherein:
Ts-ultrasonic downstream transit time in seconds(s);
Tn-ultrasonic counter-current propagation time in seconds(s);
l- -ultrasonic transmission distance in meters (m);
c- - -the propagation velocity of the ultrasonic waves in the fluid, in meters per second (m/s);
v- - -the flow velocity of the measured medium in meters per second (m/s);
theta < - > -the included angle between the flowing direction of the measured medium and the propagation direction of the ultrasonic waves, and the unit is Degree (DEG);
k, correcting the error of the pipeline flow correction coefficient;
q- - -pipe flow in cubic meters per second (m 3/s);
d- -the inside diameter of the pipe in meters (m).
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| CN201910864098.8A CN110849429A (en) | 2019-09-12 | 2019-09-12 | Oil gas recovery ultrasonic flowmeter |
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| CN201910864098.8A CN110849429A (en) | 2019-09-12 | 2019-09-12 | Oil gas recovery ultrasonic flowmeter |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114197583A (en) * | 2021-12-31 | 2022-03-18 | 上海克础机械(集团)有限公司 | Method for exporting data of non-negative-pressure water supply flow |
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2019
- 2019-09-12 CN CN201910864098.8A patent/CN110849429A/en active Pending
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114197583A (en) * | 2021-12-31 | 2022-03-18 | 上海克础机械(集团)有限公司 | Method for exporting data of non-negative-pressure water supply flow |
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