CN209067194U - A kind of composite device measuring shale gas resulting fluid mass flow - Google Patents
A kind of composite device measuring shale gas resulting fluid mass flow Download PDFInfo
- Publication number
- CN209067194U CN209067194U CN201821634797.0U CN201821634797U CN209067194U CN 209067194 U CN209067194 U CN 209067194U CN 201821634797 U CN201821634797 U CN 201821634797U CN 209067194 U CN209067194 U CN 209067194U
- Authority
- CN
- China
- Prior art keywords
- mass flow
- shale gas
- resulting fluid
- phase
- gas resulting
- 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.)
- Expired - Fee Related
Links
Abstract
A kind of composite device measuring shale gas resulting fluid mass flow, the water conservancy diversion switching device of tee tube A, rear portion including front；It is connected between tee tube A and water conservancy diversion switching device by the Venturi meter and nozzle flowmeter that are set side by side, pressure pipe is connected between Venturi meter and the arrival end and throat of nozzle flowmeter, pressure pipe is equipped with differential pressure transmitter；The end of water conservancy diversion switching device is equipped with detection pipeline；The inner wall for detecting pipeline is equipped with gamma ray emission device, the outer wall of the detection pipeline opposite with gamma ray emission device position is equipped with gamma ray receiver, and setting has the gamma radiation source of at least three kinds energy levels in gamma ray emission device.The utility model has the beneficial effects that measurement range is big；Structure is simple, small in size, convenient for safeguarding, by the way of phase oily in measurement shale gas resulting fluid, gas phase and water phase mass flow, improves work efficiency.
Description
Technical field
The utility model relates to oil and gas testing technique fields, and in particular to a kind of measurement shale gas resulting fluid mass flow
Composite device.
Background technique
In oil and gas industry, oil gas well effluent includes that the gas-liquid mixture fluid of two kinds of phases of liquid and gas is referred to as more simultaneously
Xiang Liu；Wherein, gas phase includes casing-head gas or any gas, such as methane, ethane, propane, butane etc. not coagulated at normal temperature；Liquid
It mutually again include oil phase and water phase, the liquid addition that oil mutually refers to crude oil itself and is dissolved in crude oil during oil extraction
Agent；Water phase refers to water flooding, the water injected in oil/gas well in recovery process and the other liquid additives being dissolved in water phase；
In practical situations, oil mutually may occur mutually to separate with water phase, it is also possible to which oil is mutually mixed with water phase, or emulsification completely
, wherein shale gas resulting fluid just belongs to multiphase flow scope.
Shale gas refers to the Unconventional gas preserved in series of rocks based on rich organic shale, the exploitation of shale gas well head
Object is a kind of fluid of very high oil gas water three phase of void fraction, and void fraction is even higher 85% or more, such as is up to
95%, even as high as 99%.
Shale gas preservation is biochemical genesis air and heat origin cause of formation gas continuously generated or both in mud stone or shale
Mixing, has many characteristics, such as self-generation, self-reservoir, air free water interface, large area continuously at hiding, low hole, hypotonic, generally without natural production capacity or
Low yield needs large hydraulic fracturing and horizontal well technology just to can be carried out the economic exploitation, and well yield is very low, successively decreases fast, production week
Phase is long.
Therefore, how oily phase, gas phase and water phase are real-time and accurately measured from shale gas resulting fluid after entering operation
The respective flow of three-phase is basic data necessary to Optimizing manufacture manages, to correctly hold the life of shale gas well in time
Dynamic is produced, well stimulation is effectively implemented, improves yield and recovery ratio, it is most important to carry out scientific management to oil-gas reservoir.
In the prior art, application No. is the utility model patents of CN201610581746.5, disclose a kind of measurement multiphase
The measuring device and measurement method of oil in stream, the respective volume flow of gas and water three-phase, including literary Qiu Liguan, differential pressure gauge, gamma ray
Phase fraction instrument, cyclone pipe, knockout drum etc., the program measure the body of gas phase by Venturi tube, gamma ray phase fraction instrument
After product phase fraction, by cyclone pipe, knockout drum by multiphase flow gas-liquid separation, then the volume phase of water phase and oily phase is measured respectively
Divide rate, it is respective then to obtain oil gas water three phase multiplied by the respective volume phase fraction of respective oil gas water three phase with total volumetric flow rate
Volume flow.
Although however the measurement accuracy of throttling set Venturi meter is high, its range ratio (flow rate upper limit and flow
The ratio between lower limit) very little is difficult to meet the big flow measurement of changes in flow rate generally between 3-5.
In addition, after multiphase flow is separated into gas phase and liquid phase using cyclone pipe and knockout drum in above scheme, then into
The measurement of row volume flow, while corresponding aqueous metering is carried out in fluid path, and the equipment volume of diversion cans is larger, control ring
Section is more, is not suitable for on-line measurement.
Furthermore what is measured in above scheme is the respective volume flow of oil gas water three phase, and fluid volume is by temperature change
And change, in order to reduce influence of the temperature change to measurement result, not only need to carry out the measurement result of gamma radiation device
Temperature drift correction also needs to carry out equipment at regular intervals blank pipe count value (by gamma when i.e. in pipeline without multiphase flow
The transmitted intensity values that ray reception device measures) calibration, and the gamma ray of full liquid and different single-phase mediums under full gaseity
Intensity carries out calibration.
And the quality of fluid be one not with locating temperature, pressure variation and the amount that changes, in particular, oil gas well effluent
Pressure, temperature and its ingredient be it is continually changing with flow condition, actual conditions, energy more can accurately reflect using mass flow
It is enough that more reasonably Reservoir Management and production are optimized.
To sum up, Venturi meter is used alone in the prior art that there is measurement ranges is small, separation tank volume is very much not fitted
For the defect of on-line checking, and by the way of measuring volume flow, has an impact to measurement result, need regular pair
Equipment carries out calibration and correction work, influences working efficiency.
Utility model content
The utility model provides the measurement shale gas resulting fluid matter that a kind of measurement range is big, small in size, work efficiency is high
Measure the composite device of flow.
The utility model is achieved by the following technical solution:
A kind of composite device measuring shale gas resulting fluid mass flow, tee tube A's, rear portion including front leads
Flow switching device；Connected between tee tube A and water conservancy diversion switching device by the Venturi meter and nozzle flowmeter that are set side by side
It is logical, pressure pipe is connected between Venturi meter and the arrival end and throat of nozzle flowmeter, pressure pipe is equipped with differential pressure
Transmitter；The end of water conservancy diversion switching device is equipped with detection pipeline；The inner wall for detecting pipeline is equipped with gamma ray emission device and gamma
The outer wall of the opposite detection pipeline in ray emitter position is equipped with gamma ray receiver, and setting has in gamma ray emission device
The gamma radiation source of at least three kinds energy levels.
The working principle of the utility model is: in such a way that nozzle flowmeter and Venturi meter are set side by side,
Constitute the compound flowmeter of measurement range complementation, in measurement range, the range ratio of Venturi meter, generally in 3-5
Between, reynolds number range is 2 × 105To 2 × 106Between；And the range ratio of nozzle flowmeter can achieve 10:1, Reynolds number
Range is 2 × 104To 107Between；It forms in measurement range with Venturi meter complementary.
Flow into shale gas resulting fluid from the arrival end of tee tube, by the Venturi meter or nozzle of working condition
Flowmeter measures the differential pressure Δ P between Venturi meter and the arrival end or throat of nozzle flowmeter by differential pressure transmitter；Page
Rock gas resulting fluid issues ray along pipeline radially across shale gas well head stream by detection pipeline, by gamma ray emission device
Body acquires quality phase fraction α gas, oily phase quality phase fraction α oil, water phase quality phase fraction α water of gas phase, according to shale
The hybrid density ρ of the gas phase of the practical exploitation object calibration of gas wellgas, oily phase hybrid density ρoil, water phase hybrid density ρwater, ask
Obtain the hybrid density ρ of shale gas resulting fluid；According to formula and then obtain the total mass flow rate Qm of shale gas resulting fluid, total matter
It measures flow Qm and the respective mass flow of gas and oil water can be obtained multiplied by the respective quality phase fraction of gas and oil water three-phase.
In equipment use process, first equipment is debugged, at this time water conservancy diversion switching device communication with detection pipeline and Wen Qiu
In flowmeter or nozzle flowmeter, when shale gas resulting fluid flow into equipment in, measure venturi flow by differential pressure transmitter
The differential pressure Δ P of meter and nozzle flowmeter arrival end and throat, due to square of Δ P and shale gas resulting fluid total mass flow rate Qm
It is proportional to, therefore can judge the size of shale gas resulting fluid total mass flow rate Qm according to Δ P；Shale gas resulting fluid is total
The range of flow of mass flow Qm is in the measurement range of Venturi meter, water conservancy diversion switching device communication with detection pipeline and Wen Qiu
In pipeline where flowmeter, ensure that the precision of measurement；When shale gas resulting fluid total mass flow rate Qm is not in venturi stream
Pipeline where the measurement range of meter, water conservancy diversion switching device communication with detection pipeline and nozzle flowmeter, can be to venturi stream
Flowmeter measurement less than fluid measure, improve the model of gas and oil water three-phase flow on-line checking in shale gas resulting fluid
It encloses.
The beneficial effect that the utility model generates is:
1, Venturi meter is used in combination with nozzle flowmeter, and measurement range is big；
2, structure is simple, small in size, convenient for safeguarding, being capable of oily phase, gas phase and water phase quality stream in on-line measurement shale gas
Amount；
3, by the way of phase oily in measurement shale gas resulting fluid, gas phase and water phase mass flow, it can be avoided temperature
Change the influence to measurement volume, avoids carrying out the measurement result of gamma radiation device temperature drift correction and when one section
Between to the equipment work that the intensity of gamma ray is calibrated under empty pipe condition, improve the efficiency of oil gas on-line checking.
Detailed description of the invention
Fig. 1 is nozzle flowmeter in a kind of composite device for measuring shale gas resulting fluid mass flow of the utility model
Working state schematic representation.
Fig. 2 is venturi flow in a kind of composite device for measuring shale gas resulting fluid mass flow of the utility model
Count working state schematic representation.
In figure: 1, tee tube A；2, water conservancy diversion switching device；3, Venturi meter；4, nozzle flowmeter；5, pressure pipe；6,
Differential pressure transmitter；7, pipeline is detected；8, gamma ray emission device；9, gamma ray receiver；10, temperature inductor.
Specific embodiment
It below will be with reference to the accompanying drawings in conjunction with specific embodiments to a kind of combined type for measuring shale gas resulting fluid mass flow
Device is described in detail:
Firstly, in the present invention, quality phase fraction refers to mass percent shared by each phase in shale gas, and meets
The following conditions: α gas+ α oil+ α water=1, wherein α oil indicates that oily phase quality phase fraction, α water indicate water phase quality phase
Divide rate, α gas indicates that gas phase quality phase fraction, linear quality absorption coefficient refer to every gram every square centimeter thick absorbing material, institute
The percentage of the gamma ray intensity of reduction, unit g/cm2。
According to the mixing of the hybrid density of oily phase, the hybrid density of water phase, gas phase of the practical exploitation object calibration of shale gas well
Density, oil mutually respectively the linear quality absorption coefficient to three kinds of gamma rays under working condition, water phase respectively to three kinds of gammas
Ray under working condition linear quality absorption coefficient and gas phase it is linear under working condition to three kinds of gamma rays respectively
Mass-absorption coefficient, so that it may uniquely determine oil, each phase quality phase fraction of gas and water of tested shale gas, calculation is as follows:
Wherein:
In formula:
Qo, Qg, Qw are oily phase line property amount, gas phase linear quality, water phase linear quality；
C is efflux coefficient；
ε is the compressed coefficient；
Δ P is differential pressure value；
DγGamma ray passes through the thickness of fluid, unit mm；
Nx,1、Nx,2、Nx,3The intensity in transmission of the gamma ray of respectively three kinds energy levels is measured value；
α o, 1, α o, 2, α o, 3 be the oil phase linear quality absorption coefficient to three kinds of gamma rays under working condition respectively；
α g, 1, α g, 2, α g, 3 be the gas phase linear quality absorption coefficient to three kinds of gamma rays under working condition respectively；
α w, 1, α w, 2, α w, 3 be the water phase linear quality absorption coefficient to three kinds of gamma rays under working condition respectively；
F1, f2 are respectively that the initial strength of second strand of gamma ray and third stock gamma ray is penetrated relative to first burst of gamma
The ratio of the initial strength of line is natural constant coefficient, does not change with any measuring condition.
A kind of composite device measuring shale gas resulting fluid mass flow, tee tube A's 1, rear portion including front
Water conservancy diversion switching device 2；Venturi meter 3 and nozzle stream between tee tube A 1 and water conservancy diversion switching device 2 by being set side by side
Meter 4 is connected to, and pressure pipe 5, pressure pipe 5 are connected between Venturi meter 3 and the arrival end and throat of nozzle flowmeter 4
It is equipped with differential pressure transmitter 6；The end of water conservancy diversion switching device 2 is equipped with detection pipeline 7；The inner wall of detection pipeline 7 is penetrated equipped with gamma
Line transmitter 8, the outer wall that detects pipeline 7 opposite with 8 position of gamma ray emission device are equipped with gamma ray receiver 9, gamma
Setting has the gamma radiation source of at least three kinds energy levels in ray emitter 8.
In such a way that nozzle flowmeter 4 and Venturi meter 3 are set side by side, answering for measurement range complementation is constituted
Mould assembly flowmeter；In measurement range, the range ratio of Venturi meter 3, generally between 3-5, reynolds number range 2 ×
105To 2 × 106Between；And the range ratio of nozzle flowmeter 4 can achieve 10:1, reynolds number range is 2 × 104To 107It
Between；Form in measurement range with Venturi meter 3 complementary, measurement range is big.
Wherein, the gamma ray that gamma radiation source issues can pass radially through fluid, reach the gal of detection 7 outer wall of pipeline
Horse ray receiver 9；Gamma radiation source is the gamma ray that can naturally issue at least three kinds energy levels, gamma-ray detector
9 be with the all-round spectrometry of gamma ray and analysis ability.
Flow into shale gas resulting fluid from the arrival end of tee tube A1, Venturi meter 3 by working condition or
Nozzle flowmeter 4 measures the difference between Venturi meter 3 and the arrival end and throat of nozzle flowmeter 4 by differential pressure transmitter 6
Press Δ P；Shale gas resulting fluid issues ray along pipeline radially across shale by detection pipeline 7, by gamma ray emission device 8
Gas resulting fluid acquires quality phase fraction α gas, oily phase quality phase fraction α oil, water phase quality phase fraction α water of gas phase,
According to the hybrid density ρ of the gas phase of the practical exploitation object calibration of shale gas wellgas, oily phase hybrid density ρoil, the mixing of water phase it is close
Spend ρwater, acquire the hybrid density ρ of shale gas resulting fluid；According to formula and then obtain the total mass flow of shale gas resulting fluid
Qm is measured, the respective mass flow of gas and oil water can be obtained multiplied by the respective quality phase fraction of gas and oil water three-phase in total mass flow rate Qm.
In equipment use process, first equipment is debugged, at this time 2 communication with detection pipeline 7 of water conservancy diversion switching device and text
Flowmeter 3 or nozzle flowmeter 4 in mound in shale gas resulting fluid inflow equipment, measure venturi by differential pressure transmitter 6
The differential pressure Δ P of flowmeter 3 and 4 arrival end of nozzle flowmeter and throat, due to Δ P and shale gas resulting fluid total mass flow rate Qm
Square be proportional to, therefore the size of shale gas total mass flow rate Qm can be directly judged according to Δ P；When shale gas well head stream
The range of flow of body total mass flow rate Qm is in the measurement range of Venturi meter 3,2 communication with detection pipeline of water conservancy diversion switching device
7 pipeline where with Venturi meter 3 ensure that the precision of measurement；When shale gas resulting fluid total mass flow rate Qm does not exist
The measurement range of Venturi meter 3, pipeline of the 2 communication with detection pipeline 7 of water conservancy diversion switching device where with nozzle flowmeter 4, energy
Enough fluids that Venturi meter 3 is not measured measure, and improve gas and oil water three-phase flow in shale gas resulting fluid
The range of on-line checking, and structure is simple, small in size, it is convenient for safeguarding.
In this embodiment, water conservancy diversion switching device 2 is threeway L-type anti-explosion electric valve, meets the explosion-proof of oil gas field
It is required that and the switching of control device intelligent control pipeline can be passed through.
In other embodiments, water conservancy diversion switching device 2 can also be by tee tube B and positioned at the two entrances of tee tube B
The unidirectional motor-driven valve of two of end is constituted.
In this embodiment, temperature inductor 10 is additionally provided on pressure pipe 5, temperature inductor 10 is for measuring shale
Whether gas fluid temperature uphole is in differential pressure transmitter 6 whether in working range, if overtemperature uses, will generate biggish measurement
Error and the service life for influencing differential pressure transmitter, therefore in use, it needs in the case of necessary according to temperature to differential pressure
Transmitter 6 compensates correction, so that it is affected by temperature the measurement error of generation and is in the range of class of accuracy requirement.
In this embodiment, gamma ray emission device 8 is provided with gamma radiation source Ba133, the gamma ray of sending
With tri- kinds of energy energy levels of 31keV, 81keV and 356keV.
Referring to the pertinent regulations of International Atomic Energy Agency, according to radioactive source to the potential hazard journey of human health and environment
Degree, is divided into I, II, III, IV, V class for radioactive source from high to low, and wherein the lower limit activity value in V class source is the exemption of this kind of nucleic
Activity.
In this embodiment, the exemption grade Ba of V class radioactive source is less than using activity133, to body effect pole
It is small, it ensure that the safety of manufacture, transport, displaying and application.
Grade gamma radiation source is exempted due to using, in order to which the ray for guaranteeing that ray receiver receives is more as far as possible；Gamma is penetrated
Radial distance of the line transmitter apart from detection 7 inner wall of pipeline on the other side is 12.5mm between 50mm, in this specific implementation
In example, this distance is 30mm.
It is as follows to measure shale gas resulting fluid mass flow process:
S1: flow into shale gas resulting fluid from the arrival end of tee tube A1, the Venturi meter 3 by working condition
Or nozzle flowmeter 4；
S2: the inlet port pressure P of Venturi meter 3 or nozzle flowmeter 4 is measured by differential pressure transmitter 61, throat pressure
P2And differential pressure Δ P；
S3: shale gas resulting fluid is issued ray by gamma ray emission device 8 and is radially worn along pipeline by detection pipeline 7
Shale gas is crossed, and is received by the gamma ray receiver 9 of 7 outer wall of detection pipeline, quality phase fraction α gas, the oil phase of gas phase are measured
Quality phase fraction α oil, water phase quality phase fraction α water；
S4: the hybrid density ρ of gas phase, oil phase and water phase is calculated:
ρ=ρ gas × α gas+ ρ oil × α oil+ ρ water × α water；
In formula: ρ gas is the hybrid density of gas phase, units/kg/m3；
ρ oil is the hybrid density of oily phase, units/kg/m3；
ρ water is the hybrid density of water phase, units/kg/m3；
S5: the total mass flow rate Qm of shale gas resulting fluid is calculated:
In formula: k is constant entropy coefficient；Δ P differential pressure value, unit kPa；ρ is the hybrid density of gas phase, oil phase and water phase, kg/
m3；
S6: gas phase, oil phase and the respective mass flow of water phase are calculated:
Qgas=Qm α gas
Qoil=Qm α oil
Qwater=Qm α water；
In formula: mass flow of the Qgas for gas phase, unit kg/h,
Qoil is the mass flow of oily phase, unit kg/h；
Qwater is the mass flow of water phase, unit kg/h；
Qm is the total mass flow rate of shale gas resulting fluid, unit kg/h；
α gas is the quality phase fraction of gas phase；
α oil is oily phase quality phase fraction；
α water is water phase quality phase fraction；
Wherein, k value is measured by following formula,
In formula: β is equivalent diameter ratio；
D is 4 arrival end pipe diameter of differential pressure type flowmeter 3 or nozzle flowmeter, unit mm；
D is 4 throat's pipe diameter of differential pressure type flowmeter 3 or nozzle flowmeter, unit mm；
ε is the compressed coefficient；
τ is the pressure P of 4 throat of the differential pressure type flowmeter 3 for having differential pressure transmitter 6 to measure or nozzle flowmeter2And entrance
The pressure P at end1Ratio；
C is efflux coefficient；It can be obtained according to following empirical equation:
In this embodiment, for receiving differential pressure transmitter 6, the detection signal of temperature inductor 10, and threeway L is controlled
The control device of type anti-explosion electric valve is arm processor.
It should be understood that embodiment is merely to illustrate the utility model rather than limitation the scope of the utility model.Furthermore it should manage
Solution, after reading the content taught by the present invention, those skilled in the art can make the utility model any various
Change and modification, such equivalent forms equally fall within the application the appended claims and are limited.
Claims (8)
1. a kind of composite device for measuring shale gas resulting fluid mass flow, which is characterized in that the tee tube A including front
(1), the water conservancy diversion switching device (2) at rear portion；Tee tube A(1) and water conservancy diversion switching device (2) between pass through the venturi that is set side by side
Flowmeter (3) is connected to nozzle flowmeter (4), the arrival end of Venturi meter (3) and nozzle flowmeter (4) and throat it
Between be connected with pressure pipe (5), pressure pipe (5) be equipped with differential pressure transmitter (6)；The end of water conservancy diversion switching device (2) is equipped with detection
Pipeline (7)；The inner wall for detecting pipeline (7) is equipped with gamma ray emission device (8), opposite with gamma ray emission device (8) position
The outer wall for detecting pipeline (7) is equipped with gamma ray receiver (9), and setting has at least three kinds of energy in gamma ray emission device (8)
The gamma radiation source of magnitude.
2. the composite device of measurement shale gas resulting fluid mass flow as described in claim 1, which is characterized in that water conservancy diversion
Switching device (2) includes tee tube B and two unidirectional motor-driven valves positioned at the two entrances end of tee tube B.
3. the composite device of measurement shale gas resulting fluid mass flow as described in claim 1, which is characterized in that water conservancy diversion
Switching device (2) is threeway L-type anti-explosion electric valve.
4. the composite device of measurement shale gas resulting fluid mass flow as claimed in claim 1,2 or 3, feature exist
In being additionally provided with temperature inductor (10) on pressure pipe (5).
5. the composite device of measurement shale gas resulting fluid mass flow as claimed in claim 1,2 or 3, feature exist
In gamma radiation source is Ba133, Ba133The ray of releasing has tri- kinds of energy levels of 31keV, 81keV and 356keV.
6. the composite device of measurement shale gas resulting fluid mass flow as claimed in claim 4, which is characterized in that gamma
Radioactive source is Ba133, Ba133The ray of releasing has tri- kinds of energy levels of 31keV, 81keV and 356keV.
7. the composite device of measurement shale gas resulting fluid mass flow as claimed in claim 5, which is characterized in that gamma
Ray emitter (8) to the inner wall of the opposite detection pipeline (7) in position therewith radial distance in 12.5mm between 50mm.
8. the composite device of measurement shale gas resulting fluid mass flow as claimed in claim 6, which is characterized in that gamma
Ray emitter (8) to the inner wall of the opposite detection pipeline (7) in position therewith radial distance in 12.5mm between 50mm.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201821634797.0U CN209067194U (en) | 2018-10-09 | 2018-10-09 | A kind of composite device measuring shale gas resulting fluid mass flow |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201821634797.0U CN209067194U (en) | 2018-10-09 | 2018-10-09 | A kind of composite device measuring shale gas resulting fluid mass flow |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN209067194U true CN209067194U (en) | 2019-07-05 |
Family
ID=67094385
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201821634797.0U Expired - Fee Related CN209067194U (en) | 2018-10-09 | 2018-10-09 | A kind of composite device measuring shale gas resulting fluid mass flow |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN209067194U (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109025966A (en) * | 2018-10-09 | 2018-12-18 | 重庆欣雨压力容器制造有限责任公司 | A kind of composite device and method measuring shale gas resulting fluid mass flow |
-
2018
- 2018-10-09 CN CN201821634797.0U patent/CN209067194U/en not_active Expired - Fee Related
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109025966A (en) * | 2018-10-09 | 2018-12-18 | 重庆欣雨压力容器制造有限责任公司 | A kind of composite device and method measuring shale gas resulting fluid mass flow |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| EP3095753B1 (en) | Chemical dosing device and method for dosage metering and control | |
| CN103697950B (en) | Method and device for measuring flow of oil, gas and water in non-conventional natural gas on line | |
| US10704937B2 (en) | Critical flow nozzle flowmeter for measuring respective flowrates of gas phase and liquid phase in multiphase fluid and measuring method thereof | |
| RU2542587C2 (en) | Multiphase flowmeter and fluid film measurement method | |
| CN103090917B (en) | A kind of metering device of the multiphase flow rate based on curved pipe and metering method | |
| US20100199779A1 (en) | Multiphase flowmeter using a combination of pressure differentials and ultrasound doppler readings | |
| CN106323394B (en) | Positive displacement multiphase flow mass flowmeter | |
| CN105890689B (en) | Measuring device and measuring method for measuring gas-oil-water three-phase mass flow in moisture | |
| CN100398998C (en) | Crude oil-natural gas-water three-phase flow meter | |
| CN103399025B (en) | A kind of on-line measurement is containing the method for quality sand factor in sand polyphasic flow | |
| CN203881381U (en) | Integrated device for on-line measurement of oil-water-gas three-phase flow within full-measuring-range | |
| CN103038609A (en) | An apparatus for measuring at least one characteristic value of a multiphase fluid mixture | |
| CN106706047A (en) | Underwater multiphase flowmeter based on Ba133 | |
| US8939033B2 (en) | Flow meter system and method for measuring an amount of liquid in a largely gaseous multiphase flow | |
| CN209067194U (en) | A kind of composite device measuring shale gas resulting fluid mass flow | |
| CN104007041A (en) | Device for determining content of hydrogen sulfide in coal bed | |
| US20210325220A1 (en) | Device for measuring mass flow rate of multiphase flow based on ray coincidence measurement | |
| CN104563975A (en) | Gravel packing effect detecting method and detecting device by adopting isotopic tracing | |
| CN109025966A (en) | A kind of composite device and method measuring shale gas resulting fluid mass flow | |
| WO2017206199A1 (en) | Measuring apparatus and method for measuring multiphase mass flow rates of gas, oil, and water in wet gas | |
| CN105806424B (en) | A kind of multiphase flow does not separate on-line measurement device and its measurement method | |
| US11199428B2 (en) | Device for measuring flow rate of wet gas based on an exempt radioactive source | |
| CN206114018U (en) | Measure in heterogeneous stream gas -liquid two -phase critical flow nozzle flowmeter of flow separately | |
| CN208223567U (en) | A kind of integral type gas-liquid biphase flowmeter | |
| CN202886307U (en) | Novel crude oil moisture content meter |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| CF01 | Termination of patent right due to non-payment of annual fee | ||
| CF01 | Termination of patent right due to non-payment of annual fee |
Granted publication date: 20190705 Termination date: 20211009 |