CN115586208A - Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array - Google Patents
Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array Download PDFInfo
- Publication number
- CN115586208A CN115586208A CN202211285147.0A CN202211285147A CN115586208A CN 115586208 A CN115586208 A CN 115586208A CN 202211285147 A CN202211285147 A CN 202211285147A CN 115586208 A CN115586208 A CN 115586208A
- Authority
- CN
- China
- Prior art keywords
- temperature
- phase
- oil
- fluid
- temperature sensor
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N25/00—Investigating or analyzing materials by the use of thermal means
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
Abstract
The invention relates to a device and a method for measuring the phase content of oil-water two-phase flow by an annular temperature sensor array. The heating belt is arranged outside the pipeline and used for heating the oil-water mixture in the pipeline to raise the temperature of the oil-water mixture in the pipeline; a temperature sensor is arranged on the upstream side of the pipeline, is positioned on the left side of the heating belt and is used for detecting the initial temperature of the fluid flowing into the pipeline; the annular temperature sensor array is arranged on the downstream side of the pipeline, is positioned on the right side of the heating belt and is used for detecting a temperature difference signal; the boundary layer type flowmeter measures the flow rate of the oil-water mixture in the pipeline by using the temperature difference signal. The flow velocity and the flow of the fluid in all directions can be analyzed according to the temperature rise signals measured by the temperature sensors in different directions, the temperature difference between the upstream and the downstream is corrected by utilizing the temperature signals measured by the annular temperature sensor array, and the problems of large measurement error and low measurement precision caused by the fact that the temperature difference between the upstream and the downstream is not obvious in change in a non-contact type phase fraction measurement technology can be solved.
Description
Technical Field
The invention relates to the field of oil-water two-phase flow phase content measurement, in particular to a device and a method for measuring oil-water two-phase flow phase content by using an annular temperature sensor array.
Background
For the measurement of the phase content of oil-water two-phase flow, the most original method is a manual method for timing sampling distillation assay, and the detection method has the advantages of long sampling time, high sampling randomness, incapability of carrying out online measurement and incapability of meeting the requirement of automatic management of oil field production. With the updating of measurement technology, the most widely used methods for measuring the phase content of oil-water two-phase flow at present mainly include density method, ray method, electric conduction method, capacitance method and optical non-contact measurement method. The methods mainly utilize the characteristics of different medium constants of oil and water phases, different attenuation to rays, different absorption capacity to microwaves, different refractive indexes to light and the like to measure the flow field distribution. The conductivity sensor has the advantages of simple working principle, convenient manufacturing process, low manufacturing cost, high corresponding measuring speed and the like, and is widely applied.
In the existing oil-water two-phase flow detection technology, the density method takes the density of oil-water two phases as a measurement characteristic quantity, the principle is simple, but the density difference between crude oil (especially thickened oil) and water is small, and meanwhile, a large amount of associated gas exists in the oil exploitation process, so that a large error is inevitably brought to the measurement result. The ray method has high measurement accuracy, but is expensive, contains a radioactive source, and has higher requirements on safety protection, so that the use of the products in large quantity is limited. The microwave method has high requirements on conditions such as electronic circuit and environmental interference, and the relationship between the microwave and fluid medium characteristics in actual work needs to be further defined. The capacitance method takes a two-phase capacitance value as a measurement characteristic quantity, has simple principle and low cost, but the electrode is easily influenced by factors such as corrosion, scaling, wax deposition and the like of crude oil, so that the stability and the reliability of long-term working operation are poor, and meanwhile, the dielectric constant of water is greatly influenced by the mineralization degree, and the measurement precision can be greatly influenced under the condition of high water content. Similar to the capacitance method, the conductivity method is greatly influenced by the salinity of underground water, the measurement effect is not good when the conductivity method is used alone, a probe used for measuring the local water content and the flow velocity of the conductivity sensor needs to be immersed in a fluid, and the probe is easily influenced by factors such as corrosion, scaling and wax deposition of crude oil, so that the stability and the reliability of long-term operation are poor. The non-contact optical equipment uses a non-contact on-line laser full-field measurement technology to measure the flow field in the oil pipe, and can observe the change of the flow field in the pipe more carefully, but the currently applied equipment is two-dimensional measurement equipment, certain one-sidedness and limitation exist for analyzing three-dimensional flow characteristics, most of the optical measurement equipment have strict requirements on the measured liquid, if the equipment requires that the measured liquid is strictly transparent, the laser can penetrate through the measured liquid to light tracing particles, otherwise, the measurement accuracy is influenced, and therefore the method cannot observe the flow field of the opaque crude oil in the flow process.
Disclosure of Invention
Aiming at the problems that the prior measurement technology has large error, strong measurement source radioactivity, the probe is easily corroded and scaled by immersed fluid to influence the measurement precision, non-contact optical measurement equipment cannot measure opaque crude oil and the like, the invention aims to provide a device and a method for measuring the phase content of oil-water two-phase flow by using an annular temperature sensor array. The temperature rise degree of the mixed fluid with different phase content rates after being heated is different by combining the density and specific heat capacity difference of each phase of the fluid, so that the temperature of the downstream fluid can be accurately measured by utilizing the annular sensor array, and the phase content rate can be calculated. On the basis, a temperature self-adaptive feedback adjusting unit is designed to monitor the temperature difference signal in real time, the temperature of the heating belt can be adjusted in time, the defects of the existing immersion type two-phase flow measuring technology are overcome to a certain extent, the problems of low measuring precision, radioactivity and the like are solved, and energy is saved to a certain extent.
In order to realize the purpose, the invention adopts the following technical scheme:
an annular temperature sensor array measures the device of the two-phase flow phase content rate of oil water, including:
the heating belt is arranged outside the pipeline and used for heating the oil-water mixture in the pipeline to raise the temperature of the oil-water mixture in the pipeline;
a temperature sensor disposed at an upstream side of the pipe, the temperature sensor being located at a left side of the heating belt, for detecting an initial temperature of the fluid flowing into the pipe;
the annular temperature sensor array is arranged on the downstream side of the pipeline, is positioned on the right side of the heating belt and is used for detecting a temperature difference signal; and
boundary layer formula flowmeter, boundary layer flowmeter utilize the difference in temperature signal to measure the flow of oil water mixture in the pipeline.
The heating circuit heats the heating belt; and
and the temperature difference measuring circuit measures the temperature difference to generate a temperature difference signal.
The temperature self-adaptive feedback unit monitors the temperature difference signal in real time so as to continuously adjust the temperature of the heating belt, and when the value of the temperature difference signal is too large, the temperature of the heating belt is reduced; when the value of the temperature difference signal approaches to 0, judging whether fluid flows through, if no fluid flows in, the temperature of the heating belt is reduced, if fluid flows in, the temperature of the heating belt is increased, and if the value of the temperature difference signal is in the measuring range, the temperature difference signal is output.
The annular temperature sensor arrays are uniformly distributed along the outer wall of the measured pipeline, equal angle difference exists among the annular temperature sensors, and when fluid heated by the heating belt flows through the pipeline where the annular temperature sensor arrays are located, temperature information measured by the annular temperature sensor arrays can change.
A method for measuring the phase content of oil-water two-phase flow by using an annular temperature sensor array is characterized in that the device for measuring the phase content of the oil-water two-phase flow by using the annular temperature sensor array analyzes the flow speed and flow of fluid in each direction according to temperature rise signals measured by temperature sensors in different directions, and corrects the temperature difference between the upstream and the downstream by using the temperature signals measured by the annular temperature sensor array.
The temperature difference signal is monitored in real time through the temperature self-adaptive feedback adjusting unit so as to continuously adjust the temperature of the heating belt, and therefore the temperature measurement error is reduced.
Due to the adoption of the technical scheme, the invention has the following advantages:
according to the temperature rise signals measured by the temperature sensors in different directions, the flow speed and the flow of the fluid in each direction can be analyzed; furthermore, the temperature difference delta T between the upstream and the downstream is corrected by utilizing the temperature signals measured by the annular temperature sensor array, so that the problems of large measurement error and low measurement precision caused by unobvious change of the temperature difference between the upstream and the downstream in the non-contact type phase content rate measurement technology can be solved.
Drawings
Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Like reference numerals refer to like parts throughout the drawings. In the drawings:
FIG. 1 is a schematic diagram of a principle of oil-water two-phase content measurement based on an annular temperature sensing array;
FIG. 2 is a schematic view of a single sensor distribution in a cross-section of a pipeline;
FIG. 3 is a schematic view of the distribution of an annular sensor array in a cross-section of a pipe; and
fig. 4 is a schematic diagram of a temperature adaptive feedback conditioning unit.
The reference symbols in the drawings denote the following:
1. a temperature sensor; 2. a pipeline; 3. heating the tape; 4. an annular array of temperature sensors; 5. a heating circuit; 6. a temperature adaptive feedback adjustment unit; 7. a temperature difference measuring circuit; A. the direction of fluid flow.
Detailed Description
Exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the invention are shown in the drawings, it should be understood that the invention can be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
Interpretation of terms
Boundary layer type flowmeter: the temperature distribution on the pipe wall is changed by using the convection heat transfer of the fluid flow, and the flow is measured by using the heat transfer distribution effect.
An annular array sensor: the sensor array is arranged in a ring shape and can be a ring or a plurality of rings, the shape of the ring can be a closed ring shape of a circle or an ellipse or other shapes, and the circle is adopted in the invention.
According to some embodiments of the present application, an annular temperature sensor array is provided to measure the phase content of the oil-water two-phase flow, and the oil-water two-phase flow and the phase content are measured by analyzing the distribution of the temperature field outside the pipe by measuring the temperature outside the pipe with the annular temperature sensor array.
The measuring device is constructed as shown in fig. 1, in which fig. 1, the fluid flows into the pipe 2 in the direction a.
Based on the non-contact boundary layer method flow measurement principle, a heating belt 3 with a certain length is arranged outside the pipeline 2, and an oil-water mixture in the pipeline is heated, so that the temperature of the oil-water mixture in the pipeline 2 is increased;
on the left side of the heating zone 3, i.e. upstream of the pipe 2 to be measured, a temperature sensor 1 is placed for detecting the initial temperature of the fluid flowing into the pipe (i.e. the ambient temperature), and on the right side of the heating zone 3, i.e. downstream of the pipe to be measured, a circular array sensor 4 is installed for detecting the temperature rise signal Δ T.
The temperature self-adaptive feedback adjusting unit 6 carries out self-adaptive adjustment on the temperature of the heating belt by monitoring the size of the temperature difference signal delta T so as to reduce the measurement error of the micro temperature difference delta T errors of the upper and lower streams on the oil content and finally calculate the oil-water two-phase content.
As shown in fig. 2, only a single temperature sensor is placed downstream of a conventional boundary layer mass flow meter to measure the fluid temperature rise. When the flow in the pipe is small, the temperature rise signal changes weakly, and the measurement error of a single temperature sensor is greatly increased.
According to some embodiments of the application, the annular temperature sensor array 4 is adopted to replace a single temperature sensor, and mutual correction and compensation are carried out on the temperature information received by the array sensor, so that the measurement accuracy of the phase content of the oil-water two-phase flow can be improved.
The arrangement of the annular temperature sensor array 4 outside the tube is schematically shown in fig. 3.
Because the temperature difference between the upper stream and the lower stream of the heating belt changes slightly, the measurement precision of the temperature difference delta T between the upper stream and the lower stream of the heating belt directly influences the measurement precision of the oil content.
The single temperature sensor downstream is extended to an annular array of temperature sensors 4 distributed evenly along the outer wall of the pipe under test. Assuming that the number of the annular temperature sensor arrays is N, and a certain angle difference exists between the sensors, when the fluid heated by the heating belt flows through the position of the pipeline where the annular temperature sensor arrays are located, the temperature information measured by the annular temperature sensor arrays can be changed.
According to the temperature rise signals measured by the temperature sensors in different directions, the flow speed and the flow of the fluid in each direction can be analyzed; furthermore, temperature signals measured by the annular temperature sensor array are used for correcting the temperature difference delta T between the upstream and the downstream, and the problems of large measurement error and low measurement precision caused by unobvious change of the temperature difference between the upstream and the downstream in a non-contact type phase content rate measurement technology can be solved.
According to the knowledge of fluid mechanics, there is a close relationship between the flow of fluid and the transfer of heat:
Q＝W/(C p ρΔT) (1)
in the formula (I), the compound is shown in the specification,
q is the fluid mass flow;
w is heating power;
C p is the specific heat capacity of the fluid;
ρ is the fluid density;
and delta T is the upstream and downstream temperature rise.
The temperature of the fluid measured by the upstream temperature sensor and the downstream temperature sensor of the measured pipeline is assumed to be T respectively E And T H Wherein, the upstream temperature is the initial temperature (ambient temperature) of the measured fluid, and the temperature difference measured by the upstream and downstream temperature sensors
ΔT＝T H –T E (2)
The measurement of the minute temperature difference Δ T in the equation (2) is performed based on the conventional single upstream and downstream temperature sensors shown in fig. 2.
According to the heat transfer principle, after the fluid is heated in the tube, the temperature distribution is symmetrically distributed along the axial direction, so that the formula (2) can be further changed according to the test signal of the annular temperature sensor array shown in FIG. 3
In the formula (I), the compound is shown in the specification,
T H1 、T H2 、…、T HN respectively the temperature measured by the annular array sensor at the downstream of the measured pipeline.
According to the formula (1), when addingC of the fluid when the power W and the mass flow Q of the hot zone are constant p Rho is inversely proportional to the temperature difference DeltaT, and C of the oil-water two-phase fluid p Since ρ is determined by the phase content, the water phase content is 1 to β and further the water phase content is 1 to β assuming that the oil phase content in both oil and water phases is β
In the formula (I), the compound is shown in the specification,
beta is the oil phase content;
q is the volumetric flow rate of the fluid;
C p,w and C p,o The specific heat capacities of the water phase and the oil phase are respectively;
ρ w and ρ o The densities of the aqueous phase and the oil phase are respectively represented;
the subscript o is an oil phase indicator and w is an aqueous phase indicator.
Because the specific heat capacity and the density of the oil phase and the water phase at constant pressure are approximately constant in the temperature rise change range, when the heater power W and the mass flow Q of the oil-water mixture are known, the oil phase content beta can be calculated by measuring the temperature difference signal delta T.
The temperature difference signal delta T has direct influence on the phase content of the measured fluid, the temperature measurement error can be reduced to a certain extent by adopting the annular temperature sensor array, however, the unknown quantity of the flow velocity of the fluid in the measured pipeline also has certain influence on the temperature difference signal delta T.
When the flow rate of the fluid in the pipeline is too high or no fluid flows in, the heat exchange is insufficient, the temperature difference delta T between the upstream and the downstream approaches to 0, and the phase content measurement is not facilitated;
when the flow velocity of fluid in the pipeline is slower, the heat exchange is sufficient, and the temperature of the heating belt can be properly reduced at the moment, so that low power consumption is realized.
Therefore, the temperature self-adaptive feedback adjusting unit is added to monitor the temperature difference signal delta T in real time so as to continuously adjust the temperature of the heating belt, so that the temperature measuring error can be reduced, and the energy can be properly saved. The principle of the temperature adaptive feedback regulation unit is shown in fig. 4.
As shown in fig. 4, the heating circuit 5 heats the heating belt, the temperature difference measuring circuit 7 measures the temperature difference, the temperature adaptive feedback unit 6 is arranged to monitor the temperature difference signal Δ T in real time so as to continuously adjust the temperature of the heating belt, and when the value of Δ T is too large, the temperature of the heating belt is reduced; when the value of delta T is close to 0, judging whether fluid flows through, if no fluid flows in, the temperature of the heating belt is reduced, and if fluid flows in, the temperature of the heating belt is increased; and outputting the temperature difference delta T if the value of delta T is within the measuring range.
The innovation point of the invention is based on the non-contact boundary layer type flow measurement principle, a single traditional temperature sensor distributed at the downstream of a measured pipeline is expanded into an annular temperature sensor array, and a temperature self-adaptive feedback adjusting unit is added to monitor a temperature difference signal delta T in real time, so that the temperature of a heating zone is adjusted in time; and according to the measured thermal characteristics of the oil-water two-phase fluid, realizing accurate calculation of the content of the oil-water two-phase fluid in the well.
Finally, it should be noted that: the above examples are only intended to illustrate the technical solution of the present invention, but not to limit it; although the present invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; and such modifications or substitutions do not depart from the spirit and scope of the corresponding technical solutions of the embodiments of the present invention.
Claims (10)
1. The utility model provides a device of two phase flow phase content rate of profit of annular temperature sensor array measurement, its characterized in that includes:
the heating belt is arranged outside the pipeline and used for heating the oil-water mixture in the pipeline to raise the temperature of the oil-water mixture in the pipeline;
a temperature sensor provided at an upstream side of the pipe, the temperature sensor being located at a left side of the heating zone, for detecting an initial temperature of the fluid flowing into the pipe;
the annular temperature sensor array is arranged on the downstream side of the pipeline, is positioned on the right side of the heating belt and is used for detecting a temperature difference signal; and
a boundary layer type flow meter measuring a flow rate of the oil-water mixture within the pipe using the temperature difference signal.
2. The apparatus of claim 1, further comprising:
a heating circuit that heats the heating belt; and
a temperature difference measurement circuit that measures a temperature difference to generate a temperature difference signal.
3. The apparatus of claim 1, further comprising:
the temperature self-adaptive feedback unit monitors the temperature difference signal in real time so as to continuously adjust the temperature of the heating belt, and when the value of the temperature difference signal is too large, the temperature of the heating belt is reduced; when the value of the temperature difference signal approaches to 0, judging whether fluid flows through, if no fluid flows in, the temperature of the heating belt is reduced, if fluid flows in, the temperature of the heating belt is increased, and if the value of the temperature difference signal is in the measuring range, the temperature difference signal is output.
4. The apparatus as claimed in claim 1, wherein the annular temperature sensor arrays are uniformly distributed along the outer wall of the pipe to be measured, and the annular temperature sensors have equal angular differences, so that when the fluid heated by the heating belt flows through the position of the pipe, the temperature information measured by the annular temperature sensor arrays changes.
5. A method for measuring the phase content of oil-water two-phase flow by using an annular temperature sensor array is characterized in that the device for measuring the phase content of the oil-water two-phase flow by using the annular temperature sensor array according to the claims 1-4 is used for analyzing the flow speed and the flow of fluid in each direction according to temperature rise signals measured by temperature sensors in different directions, and the temperature difference between the upstream and the downstream is corrected by using the temperature signals measured by the annular temperature sensor array.
6. The method of measuring the phase fraction of a two-phase oil and water stream using an annular temperature sensor array of claim 5, wherein the relationship between the flow of the fluid and the transfer of heat is:
Q＝W/(C p ρΔT) (1)
in the formula (I), the compound is shown in the specification,
q is the fluid mass flow;
w is the power of the heating belt;
C p is the specific heat capacity of the fluid;
ρ is the fluid density;
Δ T is the upstream-downstream temperature difference.
7. The method of claim 6, wherein obtaining the upstream and downstream temperature difference comprises: the temperatures of the fluid measured by the upstream temperature sensor and the downstream temperature sensor of the measured pipeline are respectively T E And T H The temperature difference measured by the upstream and downstream temperature sensors is as follows:
ΔT＝T H –T E (2)
in the formula
T E Is the upstream temperature, is the measured fluid initial temperature;
T H is the downstream temperature;
Δ T is the upstream and downstream temperature difference.
8. The method for measuring the phase content of oil-water two-phase flow by using the annular temperature sensor array as claimed in claim 7, wherein the temperature of the fluid is symmetrically distributed along the axial direction after the fluid is heated in the pipeline, and the formula (2) is modified according to the test signal of the annular temperature sensor array
In the formula (I), the compound is shown in the specification,
T H1 、T H2 、…、T HN respectively measuring the temperatures of different positions of the downstream annular temperature sensor array of the measured pipeline;
and N is the number of the annular temperature sensors.
9. The method of claim 8, wherein when the power and the mass flow rate of the heating zone are constant, the specific heat capacity density product of the fluid is inversely proportional to the temperature difference, the specific heat capacity density product of the oil-water two-phase fluid is determined by the phase fraction, and assuming that the oil-water phase fraction in the oil-water two-phase is β, the water phase fraction is 1- β, wherein:
in the formula (I), the compound is shown in the specification,
beta is the oil phase content;
q is the volumetric flow of the fluid;
C p,w the specific heat capacity of the water phase;
C p,o the specific heat capacity of the oil phase;
ρ w is the density of the aqueous phase;
ρ o is the density of the oil phase;
w is the power of the heating belt;
q is the fluid mass flow;
Δ T is the upstream and downstream temperature difference.
10. The method for measuring the phase fraction of a two-phase oil and water stream using an annular temperature sensor array of claim 5, further comprising: the temperature difference signal is monitored in real time through the temperature self-adaptive feedback adjusting unit so as to continuously adjust the temperature of the heating belt, and therefore the temperature measurement error is reduced.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211285147.0A CN115586208A (en) | 2022-10-20 | 2022-10-20 | Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211285147.0A CN115586208A (en) | 2022-10-20 | 2022-10-20 | Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN115586208A true CN115586208A (en) | 2023-01-10 |
Family
ID=84780718
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211285147.0A Pending CN115586208A (en) | 2022-10-20 | 2022-10-20 | Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN115586208A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117288803A (en) * | 2023-11-24 | 2023-12-26 | 抚顺市明尧石油机械有限公司 | Liquid phase sensor and method for detecting oil content of crude oil produced liquid |
-
2022
- 2022-10-20 CN CN202211285147.0A patent/CN115586208A/en active Pending
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117288803A (en) * | 2023-11-24 | 2023-12-26 | 抚顺市明尧石油机械有限公司 | Liquid phase sensor and method for detecting oil content of crude oil produced liquid |
| CN117288803B (en) * | 2023-11-24 | 2024-02-27 | 抚顺市明尧石油机械有限公司 | Liquid phase sensor and method for detecting oil content of crude oil produced liquid |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN100535612C (en) | Heat conduction sensor and measuring method thereof | |
| GB1581257A (en) | Method and apparatus for use in detecting and measuring the deposition of scale | |
| CN101113963A (en) | Method and device for measuring liquid thermal conductivity factor | |
| CN106338323B (en) | A kind of flowmeter in-situ calibration method and verification system | |
| CN103954650B (en) | A kind of solid material thermal diffusion coefficient method of testing and system | |
| CN104316115A (en) | Method for measuring pipeline flow by use of pipeline pressure drop | |
| CN109506730A (en) | Thermal flowmeter | |
| CN109387255A (en) | Thermal flowmeter | |
| CN115586208A (en) | Device and method for measuring oil-water two-phase flow phase content by annular temperature sensor array | |
| CN104515562A (en) | Multiphase flow micro-differential pressure measuring device and flow metering method | |
| CN203981621U (en) | A kind of solid material thermal diffusion coefficient test macro | |
| CN112362121A (en) | Horizontal well oil-water two-phase flow measuring method based on thermal method | |
| CN107677705A (en) | A kind of nearly horizontal oil-water two-phase flow specific retention measuring method | |
| CN111735510B (en) | Device and method for online detection of slurry solid content based on series connection of mass flow controllers | |
| CN205843740U (en) | Big orifice coal combustion gas quality flow control system in high precision | |
| CN212622062U (en) | On-line slurry solid content detection device based on series connection of mass flow controllers | |
| CN102645248B (en) | Self-correction heat type-precession vortex combined type gas flow measurement method | |
| Rackemann et al. | Determining circulation velocities in vacuum pans | |
| CN111504405B (en) | Pipeline flow measuring device and method based on convective heat transfer phenomenon | |
| CN111007112B (en) | System and method for online measurement of steam humidity based on conductivity method | |
| US20030221483A1 (en) | High accuracy measuring and control of low fluid flow rates | |
| CN209821012U (en) | Detect device of oil high temperature viscosity | |
| CN112525369A (en) | Platinum resistor temperature sensor packaging structure and temperature measurement using method thereof | |
| Arpino et al. | Environmental Effect on Temperature Measurement in Natural Gas Network Balance | |
| CN110133085A (en) | Million kilowatt nuclear power station pH in-line meter test macro and method |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |