43 results about "Fluid type" patented technology

The application discloses a kind of cross-tectonic period diagenesis simulation device and method.The device includes fluid driving system, reaction solution supply system and at least two groups of tectonic period reaction system connected in sequence, and different reaction systems are used to simulate the temperature and pressure conditions when geological fluid passes through each target layer during cross-tectonic period.The method first restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period according to petrology and geochemistry analysis, combined with tectonic evolution history, burial history and fluid injection history, establishes cross-tectonic period diagenesis model, determines geological fluid type, and then determines the process of geological stress driving high-pressure layer fluid to migrate to low-pressure layer, restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period;According to the restored geological process and geological conditions, the forward simulation of fluid dissolution, cementation, metasomatism and other diagenesis during cross-tectonic period is carried out by using cross-tectonic period diagenesis simulation device.Provide basis for judging the diagenetic mechanism of reservoir rock after high temperature and high pressure and multi-stage tectonic evolution.

The invention provides a micro-aperture endoscopic detection and directional cleaning method which comprises the following steps: acquiring an inner wall image and medium information of a target pipeline, and performing feature analysis on the inner wall image to obtain a dirt type; determining the spraying state of a nozzle according to the dirt type; wherein the injection state comprises injection pressure and injection direction; cleaning liquid information is determined according to the spraying state and the medium information; wherein the cleaning fluid information comprises cleaning fluid types and a cleaning fluid proportion, and the cleaning fluid types comprise external cleaning fluid and / or pipeline medium fluid; and generating a directional cleaning scheme for the target pipeline according to the spraying state and the cleaning liquid information. The position and the type of the dirt are determined by obtaining the internal image, the dirt is removed in a targeted mode, the equipment applicability is improved, the working efficiency is improved, and meanwhile damage to the pipeline is reduced.

The application provides a dense reservoir fluid identification method based on physical data double driving, comprising: performing abnormal value correction and fluid category direct marking on conventional logging data to obtain labeled logging data; performing signal self-adaptive time-frequency conversion on the labeled logging data, and calculating porosity, permeability and water saturation to output physical prior feature channels; inputting two-dimensional multi-channel time-frequency spectrum and the physical prior feature channels into a pre-constructed MDSC-TAM neural network model to extract hidden logging signal frequency domain spectrum series structure and global sedimentary rule to obtain a dense reservoir fluid identification result; and performing physical perception constraint and decision output on the fusion feature representation to obtain a fluid type and confidence. The application solves the data scarcity and model black box bottleneck, improves the engineering practicability of the algorithm, and realizes high-precision identification of the dense reservoir fluid and enhanced physical interpretability.

The design method of the high-energy additional fluid discharge structure of the ship condenser relates to the field of high-energy fluid discharge of the surface condenser of the energy power system. It solves the problem that the existing condenser structure design method only considers the energy level reduction and does not consider the optimization of the structural parameters, resulting in the incompatibility of the input high parameters (temperature, pressure, etc.) with the actual application scenario in a small space. The present invention determines the fluid type according to the input fluid thermodynamic parameters and the condenser saturation parameters; determines the fluid energy level according to the water inlet / steam port inner diameter and the fluid thermodynamic parameters; judges the condenser body water inlet / steam port position according to the fluid deoxygenation state or the fluid energy level; determines the type and parameters of the selected diffusion element according to the fluid energy level; evaluates the life of the diffusion element to judge whether the life of the diffusion element meets the service life requirements. If the result is yes, the process ends; if the result is no, the curvature and thickness of the diffusion element are adjusted to meet the service life requirements. The present invention is mainly used for condenser structure design.

The utility model relates to a tubular static mixer. Comprising a tubular mixer main body and a plurality of mixing units which are sequentially arranged along the axial direction of the mixer main body, each group of mixing units comprises a group of spiral twisted blades and a splitter plate; the screw pitch and the twisting angle of the twisted blade are dynamically adjusted according to the fluid viscosity; a left-handed structure and a right-handed structure are arranged at the two ends of the mixing unit respectively and are connected in a cross shape through clamping grooves to form four flow channels; adjustable connectors are arranged at the two ends of each mixing unit and are used for adjusting the distance between the mixing units or replacing the modularized mixing units. The problems that in the prior art, a tubular static mixer still has a certain improvement space in the aspects of mixing efficiency, applicable fluid type range, blockage prevention and the like, for example, when some fluids with large viscosity difference are mixed, ideal mixing uniformity is difficult to achieve, meanwhile, a mixing element is prone to blockage, and the mixing efficiency is poor are solved. And normal operation of equipment is influenced.

The application discloses a multiphase fluid flowmeter, which comprises a flowmeter base, at least two pressure sensors and at least one pressure reducing device; the pressure reducing device is arranged in the flowmeter base, and the pressure sensors are arranged at two ends of the pressure reducing device. The flowmeter does not need movable structures such as impellers to calculate flow, so that the flowmeter is simple and exquisite in structure, differential pressure measurement and flow conversion can provide a wider linear region, and the design without movable structures can ensure accuracy and facilitate replacement, so that the flowmeter can not be limited by fluid types and viscosity, and has a wider application range.

The application provides a tubing leakage DAS monitoring physical simulation experiment device and experiment method, and belongs to the technical field of oil and gas well safety monitoring.The application constructs a physical simulation experiment device composed of a distributed optical fiber acoustic wave monitoring system, a wellbore leakage simulation system, a liquid supply system and a waste liquid recovery system, sets a leakage point simulation assembly with a replaceable leakage channel at a preset position of the simulated wellbore, simulates tubing leakage working conditions under different leakage point positions, leakage point forms, injection flow rates and fluid types, collects acoustic wave profiles of the whole wellbore section by using the distributed optical fiber acoustic wave monitoring system, and constructs a quantitative relationship model of leakage flow rate and acoustic wave energy.The application can simulate complex leakage working conditions of oil and gas wells, realizes rapid replacement and comparison experiments of various leakage point forms, overcomes the limitation of single leakage point type of traditional experiment devices, and provides experiment support for accurate positioning and quantitative evaluation of tubing leakage points based on optical fiber acoustic wave monitoring.

Systems and devices related to smart regulators and smart manifolds for welding-type systems are disclosed. The smart regulators can be coupled to fluid tanks and provide information about current pressure(s) and / or flow rates to remote devices and / or operators. The remote devices can also determine and / or output additional information, such as remaining fluid and / or the time remaining before a fluid runs out or becomes dangerously low. The smart manifolds can be configured to work with several different fluid supply devices. In this way, an operator can easily mix multiple fluid types, switch between different fluid types, and / or switch between different fluid tanks.

The application discloses a fluid type acceleration sensor, a preparation mold and a preparation method. The fluid type angular acceleration sensor comprises a shell, three semi-canal and a container connecting the semi-canal, a channel for liquid circulation is arranged in the semi-canal, the container has a cavity, the cavity is communicated with the channel of each semi-canal to jointly form a closed fluid cavity, wherein the central axis of the three semi-canal respectively bends and extends in three planes, the three planes pass through an original point and are perpendicular to each other, three ampulla caps are correspondingly arranged in the semi-canal, the edge of the ampulla cap is connected with the semi-canal to close the channel, the ampulla cap can be deformed by being pushed by the liquid in the channel, and three strain gauges are correspondingly arranged in the ampulla cap and are configured to follow the deformation of the ampulla cap and convert the deformation into an electric signal output. The fluid type acceleration sensor, the preparation mold and the preparation method can provide more accurate and reliable angular acceleration signals.

This invention provides a fluid component and a method for generating its fluid layout. The fluid component includes: at least one first pipe, each first pipe being connected to a fluid conveying device; wherein the fluid conveying device includes a distributor, at least one second pipe connected to the distributor, and the other end of all or part of the second pipes connected to a fluid storage device; each second pipe is equipped with a power device; the distributor is also connected to the first pipe; a check valve is provided between the power device and the distributor; and a control device is also included, connected to each power device, for generating control commands according to a preset fluid layout, and controlling the opening and closing of the power devices according to the control commands; the fluid layout represents the fluid type at each position in the first pipe. This invention enables fluid to flow in the first pipe according to a preset fluid layout, thereby expressing information through the fluid-carrying first pipe, with a relatively simple structure.

A pump system for selectively extracting nonaqueous phase liquids (NAPLs) from groundwater includes a fuel pump with current monitoring and a control assembly. The system utilizes a conductive probe within a probe body to detect a fluid interface, distinguishing NAPLs from water by measuring conductivity. The control assembly monitors the pump's current draw and adjusts operation to avoid water intake, thereby protecting the pump from damage. The probe body features an insulated shell to ensure accurate readings, and the control assembly uses real-time data to activate or deactivate the pump based on fluid type. The system is further configurable to calibrate for various contaminant conditions, optimizing efficient NAPL extraction from contaminated environments.

A method of identifying inflow locations along a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

The application discloses a formation porosity measurement method, system, logging instrument and medium, and relates to the field of oil and natural gas development. First, the hot neutron counts detected by a first hot neutron detector and a second hot neutron detector in a D-D neutron porosity logging instrument are acquired respectively. Then, gamma time spectrum information detected by a gamma detector in the D-D neutron porosity logging instrument is acquired, and a wellbore Sigma value is determined according to the gamma time spectrum information. Finally, the formation porosity is determined by combining the first hot neutron count, the second hot neutron count and the wellbore Sigma value. The scheme does not need to measure the wellbore size and the fluid type, and improves the accuracy of formation porosity calculation.

The embodiment of the invention provides a converter station fire-fighting foam pipeline leakage point detection method and device, and the method comprises the steps: obtaining a first data set based on the fluid data collected by a collection point of a foam pipeline; based on the first data set and a preset fluid identification model, determining a fluid type which is Newtonian fluid or non-Newtonian fluid; and determining a leakage point identification result based on a leakage point identification model corresponding to the fluid type and the first data set. According to the invention, leakage in the foam pipeline can be rapidly and accurately detected.

The invention discloses a strike-slip fracture control carbonate rock fracture-cavity reservoir fluid discrimination device and method. The device comprises a data acquisition module, a data preprocessing module, a strike-slip fracture construction module, a feature dimension reduction module and a fluid discrimination module. Wherein the data acquisition module is used for acquiring seismic data, multi-type logging data and oil testing results of multi-type logging; the strike-slip fracture construction module is used for constructing a reservoir model and determining a fluid gathering target region based on the reservoir model; the data preprocessing module is used for preprocessing the logging parameter data of the fluid gathering target area; the feature dimension reduction module is used for screening features by using a filtering method and a wrapping method and carrying out data dimension reduction; and the fluid discrimination module is used for constructing a sample set and discriminating the fluid property of the fractured-vuggy carbonate reservoir by using a cost-sensitive learning method. According to the method, the judgment precision is improved by considering the cost difference of misjudgment of different fluid types.

This invention provides a method and system for fluid identification in tight sandstone gas-bearing formations. It employs a combined three-porosity logging method, a combined nuclear magnetic resonance (NMR) logging and density logging method, and a combined NMR logging and three-porosity logging method for fluid identification in tight sandstone gas-bearing formations. The method constructs multiple gas-bearing formation sensitive factors through theoretical analysis, amplifying the differences between gas-bearing formations and building fluid identification charts. In the interpretation of new target layers, fluid discrimination is performed based on each chart, and the final interpretation result is determined using the chart consistency rate method or the absolute majority voting method. The fluid sensitive factors constructed in this invention, and the cross-plots built based on these factors, can effectively distinguish fluid types. The comprehensive discrimination strategy organically combines the results of multiple methods, eliminating the limitations of any single method. The interpretation results have been verified by oil testing, showing a significantly improved consistency rate.

This invention provides a knowledge- and data-driven drilling and completion fluid design expert system, belonging to the field of reservoir protection technology in the petroleum industry. The system includes: a total skin factor calculation module for calculating the total skin factor of a target well; and an optimization module for determining that the drilling and completion fluids corresponding to the target well have good performance and require no optimization design when the total skin factor of the target well is less than or equal to 0; and for optimizing the drilling and completion fluids corresponding to the target well when the total skin factor of the target well is greater than 0, by: determining a target drilling fluid formula based on the permeability and / or structural characteristics of the reservoir corresponding to the target well, and pre-setting drilling fluid formulas corresponding to different permeability and / or structural characteristics; and determining a target completion fluid formula based on the type of completion fluid corresponding to the target well and pre-setting completion fluid formulas corresponding to different completion fluid types.

The invention provides a processing method of two-dimensional nuclear magnetic resonance logging data, and belongs to the technical field of oil-gas exploration. In order to solve the problem of two-dimensional nuclear magnetic resonance fluid component evaluation, a spectrum peak automatic division method is adopted to process two-dimensional nuclear magnetic resonance logging data, firstly, a spectrum peak signal boundary of each component in a two-dimensional spectrum is determined by adopting an amplitude reduction clustering algorithm, and overlapped fluid components are further divided by utilizing a Gaussian mixture model clustering algorithm; according to the method, the fluid boundary division precision is improved, so that a fluid identification chart of each depth point is formed, the fluid type is determined according to the distribution position of main spectral peaks, the fluid volume of each component is calculated, and identification and content calculation of various fluids in a reservoir are realized. The technical bottleneck of two-dimensional nuclear magnetic resonance fluid component automatic division and quantitative evaluation is overcome, and the method has remarkable application value and popularization prospect in unconventional oil and gas reservoir exploration.

The invention relates to the technical field of geophysical well logging interpretation, in particular to a compact sandstone reservoir complex fluid self-adaptive identification method and device, and the method comprises the steps: analyzing the relation between different fluid types and lithology, physical property, pore structure and brittle reservoir characteristic parameters in a histogram and cross plot mode, and qualitatively determining the main control elements of the fluid type difference; constructing required quantization parameters according to the main control elements; performing normalization processing on the logging curve and the quantization parameters; selecting sensitive parameters from the existing logging curve and the constructed quantization parameters by using a spider diagram; fusing the multiple parameters by using a principal component analysis method, and constructing fluid type master control elements; establishing a label database according to the constructed index and the corresponding fluid type; and training and self-adaptive explanation of a complex fluid identification model are carried out. According to the method, the recognition precision of the complex fluid of the compact sandstone reservoir is improved, and a geological foundation is laid for subsequent dessert evaluation and target optimization.

The invention relates to the technical field of oil and gas field exploitation, in particular to a core type adaptive SC-CO2 phase state stress collaborative fracturing method. The method specifically comprises the steps that fracturing experiments under various variable conditions are carried out, and fracturing pump pressure is obtained; the variable conditions comprise a core type, an injection fluid type, an injection flow rate and axial pressure and confining pressure conditions; converting the core type and the injected fluid type into virtual variables; establishing a multiple linear regression model by taking the fracture pump pressure as a dependent variable and taking the core type, the injection fluid type, the injection flow rate and the difference between the axial pressure and the confining pressure as independent variables; fitting by adopting a least square method to obtain a regression coefficient of each independent variable; performing t inspection to obtain a p value of each independent variable, and screening out the independent variables with the p values smaller than or equal to 0.2; and supercritical CO2 phase state stress synergistic fracturing is carried out. The method solves the problems that an existing method is unstable in effect in practical application, and the diversified requirements of different unconventional reservoirs are difficult to meet.

This invention provides a fluid identification method, apparatus, processor, and machine-readable storage medium, relating to the field of reservoir logging evaluation. The method includes: determining logging parameters of the test layer, adjacent standard water layer, and fluid type at multiple test depths of the tested formation; determining the invasion factor and oil-bearing discrimination index at each test depth; establishing a fluid cross-plot using the oil-bearing discrimination index, invasion factor, and fluid type at multiple test depths; determining the oil-water boundary based on the fluid cross-plot; determining the target layer logging parameters and adjacent standard water layer logging parameters at the depth to be tested; determining the invasion factor and oil-bearing discrimination index at the depth to be tested; and determining the fluid type at the depth to be tested using the fluid cross-plot, the oil-water boundary, and the oil-bearing discrimination index and invasion factor at the depth to be tested. This invention simplifies the fluid identification process and accurately identifies the fluid properties in underground reservoirs.

The invention belongs to the technical field of geophysical logging, and relates to a method and a system for quickly identifying fluid properties under the coexistence of hydrates, free gas and water, a hydrate layer, a free gas layer and a mixed layer with clear fluid properties are used as characteristic reservoirs, and a characteristic reservoir logging curve is selected from target reservoir logging curves; fluid indication coefficients are obtained according to the acoustic derivative parameters calculated by the characteristic reservoir logging curve, and acoustic derivative parameters sensitive to fluid property changes are screened out according to the fluid indication coefficients; calculating an elastic constant coefficient according to the screened acoustic derivative parameters; establishing an intersection chart based on the resistivity and the longitudinal wave time difference and an intersection chart based on the longitudinal wave time difference and the elastic constant coefficient; and the non-diagenesis hydrate-containing stratum is effectively divided based on the two different intersection charts. According to the method, the recognition precision and efficiency of the complex fluid of the non-diagenesis hydrate-containing stratum can be remarkably improved, and therefore precise recognition of different fluid types is achieved.

The invention discloses a reservoir fluid type identification method and device, a storage medium and equipment. The method comprises the following steps: performing logging data acquisition on a target reservoir based on a single-set parameter acquisition mode of nuclear magnetic resonance logging to obtain nuclear magnetic resonance logging information of the target reservoir; calculating the porosity and the nuclear magnetic resonance geometric mean value of the target reservoir based on the nuclear magnetic resonance logging information, and respectively obtaining a porosity curve and a nuclear magnetic resonance geometric mean value curve of the target reservoir; identifying a typical water layer section of the target reservoir, and adjusting the scale ranges of the porosity curve and the nuclear magnetic resonance geometric mean curve to enable the two curves to coincide at the layer section; and determining the fluid type of the target reservoir section based on the matching condition of the reservoir porosity curve and the nuclear magnetic resonance geometric mean curve in each reservoir section. The method can realize rapid and visual reservoir fluid type identification.

Systems, methods, and apparatuses for generating a fluid analysis report with key issues to improve vehicle maintenance are provided. A processing circuit is configured to: obtain information regarding a plurality of fluids from a plurality of vehicles; determine a plurality of thresholds based on the information; analyze a fluid sample from a particular vehicle to identify a fluid type of the fluid sample; identify a vehicle type of the particular vehicle associated with the fluid sample; retrieve a population of the obtained information pertinent to at least one of the identified fluid type of the fluid sample or the vehicle type of the particular vehicle; retrieve at least one threshold associated with the retrieved population; compare a characteristic of the fluid sample to the retrieved at least one threshold; and generate and provide a dynamic graphical user interface regarding the comparison to a computing device.

The invention provides a cloud conglomerate well logging identification method and device, electronic equipment, a medium and a product, and the method comprises the steps: obtaining neutron porosity well logging data and volume density well logging data of a plurality of measurement points of a standard mudstone section of a standard well, and carrying out the data relation fitting, and obtaining a fitting coefficient; calculating a neutron fitting density value based on the neutron porosity and the fitting coefficient of the oil well formation testing perforation section; a first porosity is calculated based on the volume density of the oil well formation testing perforation section, a second porosity is calculated based on the neutron fitting density value, and a porosity difference value is calculated based on the first porosity and the second porosity; and drawing an oil-gas-water identification chart of a plurality of fluid type areas divided based on the oil testing result on the basis of the porosity difference values of the plurality of oil well oil testing perforation sections, the gas logging total hydrocarbon and the oil testing result so as to predict the fluid type of the non-oil-testing new well perforation section. According to the method, oil, gas and water of the cloudy sandstone tight reservoir can be quickly and accurately identified, and the exploration cost is reduced.

A piston for a fluid machine, intended to be mounted at least partially inside a bushing of the fluid machine in such a way as to be relatively reciprocally movable relative to the bushing, the piston extending in a main direction and comprising a head having a first end of the piston and a shaft having a second end of the piston, according to the invention, the first end is intended to define a fluid expansion and / or compression chamber together with a bushing of the machine, the shaft comprising a side wall provided with at least one annular groove defined between a first and a second castellated member, the groove being equipped with a gasket-type seal for cooperating in a sealing manner with the side wall of the bushing, the seal is provided with a through-hole allowing fluid flow from the expansion and / or compression chamber to the second end, the seal comprising a cavity separate from the through-hole, the cavity comprising a compression system for pressing the seal against the first and second castellated members in the main direction, the compression system being of mechanical and / or fluidic type. The invention further relates to a fluid machine.

The invention relates to the technical field of oil-gas exploration and development, and particularly discloses a seismic-electric fusion reservoir fluid identification method, which comprises the following steps of: firstly, obtaining a three-dimensional seismic horizon, further obtaining a geological framework of a work area according to the three-dimensional seismic horizon, and inverting electromagnetic data to obtain an inversion resistivity profile; and the inversion resistivity of the target stratum of the work area is obtained by combining the geological framework and the inversion resistivity profile. And based on the resistivity fluid type cross plot, the fluid type of the target layer can be identified by the inversion resistivity of the target layer. Compared with a traditional fluid identification technology, the reservoir fluid identification method integrates the spatial distribution depiction advantage of well-to-seismic combination and the advantage that an electrical method is sensitive to fluid, is not limited to identification of the fluid at the drilling position, can accurately identify the fluid of each reservoir in a work area, and is high in fluid identification accuracy, large in identification range and easy to operate.

The embodiment of the present application relates to the technical field of oil and gas field exploration and development geology, and discloses a method and equipment for identifying fluid type of tight sandstone gas reservoir by well logging, which comprises the following steps: obtaining sensitive well logging curves of blind wells in the tight sandstone gas reservoir; the fluid type of the blind well is unknown; identifying the fluid type of the blind well according to the sensitive well logging curves of the blind well and a pre-generated fluid determination model; the fluid determination model is generated by a pre-generated convolutional neural network and an integrated algorithm model, the convolutional neural network is used to extract first feature data of the sensitive well logging curves of the blind well, the integrated model is composed of multiple machine learning models and is used to identify the fluid type of the blind well according to the first feature data, and the convolutional neural network comprises a fully connected layer. The method provided by the present application avoids the significant difference of the well logging identification effect of a single algorithm model on the fluid type of the tight sandstone gas reservoir, and significantly improves the overall identification stability and accuracy of the model.

The invention discloses a tight gas reservoir fluid occurrence and fracturing fluid water blocking damage evaluation system and method.The tight gas reservoir fluid occurrence and fracturing fluid water blocking damage evaluation method comprises the steps that a rock core sample is taken out of a tight gas reservoir; the method comprises the following steps: performing a series of treatment on a rock core sample, and establishing a fluid occurrence chart capable of distinguishing different fluid types in a rock core by utilizing a nuclear magnetic resonance T1-T2 spectrum technology; the method comprises the following steps: injecting fracturing fluid into a rock core sample to simulate water blocking damage, then performing gas displacement under different injection pressure differences, and analyzing a nuclear magnetic resonance T1-T2 spectrum based on a fluid occurrence chart so as to qualitatively evaluate the retention state of the fracturing fluid. According to the water blocking damage evaluation method based on the nuclear magnetic resonance T2 and T1-T2 technology, accurate quantification of the water blocking damage degree can be achieved by analyzing distribution and migration characteristics of fluid in a reservoir rock core sample, and a theoretical basis and an experimental means are provided for making blocking removal measures.

The invention discloses a multi-stage focusing entangled fluid type large-phase-ratio coupling precise opposite spraying microreactor, a tannin germanium precipitation method and application in heavy metal separation, and relates to the technical field of hydrometallurgy and resource recycling, an inlet A and an inlet B are arranged front and back, the inlet A is divided into an A1 microchannel outlet and an A2 microchannel outlet in the reactor, the caliber of the outlet is adjustable within 0.1-30 mm, and the inlet B is divided into an inlet A and an outlet B; preferably, the thickness is 0.3 to 1mm; an inlet B at the front part is only provided with an internal pipeline, the caliber of an outlet is adjustable in a range of 0.1-30mm, preferably 0.3-1mm, and the outlet extends downwards from the right lower part of the reactor and is intersected with A1 and A2 at a convergent point C at an included angle of 22.5 + / -22.5 degrees respectively; the A is connected with a large-volume phase injection pump, the B is connected with a small-volume phase injection pump, and the liquid phase ratio of 1: 1-50: 1 is achieved by adjusting the pump speed and the pipeline diameter. The microreactor has the advantages that the reaction efficiency is revolutionarily improved, the resource consumption is greatly reduced, the metal separation selectivity is broken through, the industrial application advantage is achieved, the environmental benefit is remarkable, and practical use is facilitated.