96 results about "Fluid type" patented technology

The invention provides a reflux valve supporting remote monitoring of the Internet of Things. The reflux valve comprises a valve body provided with a fluid inlet, a fluid outlet and an internal flow channel, and an electric actuating mechanism is configured for controlling the opening degree of the valve; a microprocessor and a memory are arranged in the control unit, and the control unit processes data of the sensor, calculates a fluid density correction coefficient and a pressure correction coefficient, corrects original flow data collected by the flow sensor and generates an actual flow value; the control unit further identifies the current fluid type and adaptively adjusts the countercurrent detection threshold value of the upstream and downstream pressure difference based on the relationship between the flow and the pressure data; when the pressure difference exceeds the adjusted threshold value, the electric executing mechanism executes emergency turn-off operation; meanwhile, a wireless communication unit is arranged, real-time data transmission is supported, control parameters issued by external monitoring equipment are received, and intelligent control and remote management are achieved; the intelligence and the operation efficiency of the reflux valve can be effectively improved, and the reflux valve is suitable for safety protection and operation optimization under the complex fluid working condition.

A fluid injector system includes at least one injector for pressurizing and delivering at least one fluid from at least one fluid reservoir, at least one fluid path section providing fluid communication between a bulk fluid reservoir and a syringe connected to the at least one injector, and at least one sensor arranged along the at least one fluid path section. The at least one sensor includes an emitter configured to emit light through the at least one fluid path section, and a detector configured to receive the light emitted through the at least one fluid path section and generate an electrical signal based on at least one property of the received light. The fluid injector system may further include at least one processor programmed or configured to determine, based on the electrical signal generated by the detector, at least one of an identity of the at least one fluid present in the fluid path section, a concentration of the at least one fluid in the fluid path section, and at least one property of the fluid path section.

The invention discloses a reservoir fluid identification method, device and equipment and a medium, and relates to the technical field of oil and gas field exploration. The invention provides a multi-level nested reservoir fluid identification method based on geological mode constraint for double-medium tight sandstone. For different reservoir types, a preset algorithm is utilized to fuse the comprehensive logging parameters and the proposed fluid sensitive factors suitable for the double-medium tight sandstone, and fluid discrimination parameters suitable for different reservoir types are constructed. On the basis, reservoir types are divided by comprehensively considering the coupling action result of the matrix and the tectonic fracture, the difference of fluid characteristics of different reservoir types is determined, and based on the classification constraint of a geological mode, the different reservoir types are divided, and the fluid type of the tight sandstone reservoir is identified by using an integrated identification model. Logging curve data for fluid identification are easy to obtain, the fluid identification precision is high, the identification efficiency is high, and the method can be widely applied to reservoir fluid identification of double-medium tight sandstone.

A method to offer insight on reservoir compartmentalization through the automation of single- and multi-well formation pressure analysis. The method specifically accounts for the measurement uncertainty and any prior information about the reservoir to draw evidence on at least one of a fluid type, a locating feature of the at least one fluid body, vertical compartmentalization, and lateral compartmentalization.

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 fluid type shaft driving mechanism which comprises a cylinder body, a main shaft and a transmission arm, the transmission arm is arranged in the cylinder body and can rotate in the cylinder body around the axis of the main shaft, and the cylinder body is divided into a first cavity and a second cavity by the transmission arm. The first sealing bag body is arranged in the first cavity, the second sealing bag body is arranged in the second cavity, and fluid connectors are arranged on the first sealing bag body and the second sealing bag body. When the fluid enters the first sealing bag body, the transmission arm is pushed to move towards the direction of the second cavity; and when the fluid enters the second sealing bag body, the transmission arm is pushed to move towards the direction of the second cavity. According to the fluid type shaft driving mechanism, the manufacturing cost is reduced, and the output torque of the swing driving mechanism is improved.

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 invention discloses a pressure building monitoring safety pressure relief gate valve, belongs to the technical field of gate valve monitoring, and solves the problems that the service life is limited when the pressure building phenomenon in a middle cavity of a double-gate-plate gate valve is solved in a mechanical structure mode, and the pressure in the middle cavity is too large or the pressure building phenomenon in the middle cavity continues to be too long. The problem that the automatic pressure relief device cannot be used due to the fact that the automatic pressure relief device exceeds the stress limit or the working fatigue limit of the automatic pressure relief device is solved. The pressurizing pipeline and the pressure relief pipeline are communicated with the middle cavity and the outlet end. When the system works, the double-gate-plate blocking gate valve and the middle cavity are closed, the electric control module controls the electromagnetic valve to enable the Y-shaped stop valve to be communicated with the pressurizing pipeline and pressurizes fluid in the middle cavity, the system judges the fluid type through pressure change, a model matching database is combined, the fluid type is confirmed and the pressure building time is pre-judged, and the electric control module controls the electromagnetic valve according to the pressure building time. The Y-shaped stop valve is communicated with the pressure relief pipeline in advance, pressure is relieved immediately when fluid expands, the service life of the valve rod and the gate frame is prolonged, and overload work is avoided.

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 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 invention discloses an earthquake comprehensive prediction method for shallow complex oil and gas type identification, and the method comprises the steps: building a rock physical model suitable for a research region for fluid replacement through the statistics of drilled well data in the research region on the basis of an AVO technology; then, a P-G cross plot is made by using a reflection coefficient approximation formula in combination with the logging data and the fluid replacement data; performing linear fitting on the discrete sample points according to different fluid types, determining the positions of a waterline, an oil line and a gas line, and defining the fluid types in different areas; and finally, qualitatively determining the fluid property according to the position distribution of the target layer sample points in the research area on the template. According to the method, seismic data and logging data are comprehensively utilized, the AVO template suitable for a research area is established, the requirement for logging data is lowered, fluid types can be rapidly identified before drilling only through elastic information of strata, meanwhile, the transverse and longitudinal distribution range of oil and gas is predicted, efficiency and identification accuracy are greatly improved, and the method is suitable for popularization and application. And meanwhile, the production cost is greatly reduced.

Aspects of the subject technology relate to systems and methods for determining positions of fluids during a cementing process in real-time. Systems and methods are provided for receiving one or more sensing parameters from a distributed acoustic sensing fiber optic line positioned in a wellbore during a cementing process, determining types of fluid proximate to the wellbore based on the one or more sensing parameters received from the distributed acoustic sensing fiber optic line, determining pressure gradients of the types of fluid based on the one or more sensing parameters received from the distributed acoustic sensing fiber optic line, and compiling flow profiles for the types of fluid proximate to the wellbore based on at least one of the determining of the types of fluid and the determining of the pressure gradients of the types of fluid.

The utility model discloses an intelligent fluid type electric heating box, which belongs to the technical field of electric heating boxes and comprises a material pipe, a position limiting frame mounted on one side in a U-shaped clamping plate, a push plate slidably mounted in the position limiting frame, an ultrasonic probe mounted on one side of the push plate, and an ultrasonic thickness gauge mounted on the outer surface of the material pipe. The compression spring pushes the push plate and the ultrasonic probe to move towards the inner wall of the material pipe by using the restoring force of the compression spring, so that the ultrasonic probe is tightly attached to the inner wall of the material pipe, the ultrasonic thickness gauge is controlled, the ultrasonic probe is used for detecting the interior of the material pipe, and the thickness of scale attached to the inner wall of the material pipe is conveniently detected; whether the heating effect of the electric heating box is interfered or not is speculated according to the scale thickness, the use safety of the electric heating box is improved, an air extracting pump is started, air in the containing box is extracted, the air flows into the containing box through an air inlet hole, a heat insulation pipe and an open hole, and the interior of the containing box is cooled.

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 invention discloses a glauconite-containing sandstone reservoir fluid identification method, device and equipment and a medium. The method comprises the following steps: determining the porosity of a target glauconite-containing sandstone reservoir, and determining the reservoir type of the target glauconite-containing sandstone reservoir according to the porosity; if the reservoir type is a reservoir, characteristic parameters of a target glauconite-containing sandstone reservoir are obtained, the porosity and the characteristic parameters are input into an identification model, a fluid identification value of the target glauconite-containing sandstone reservoir is obtained, and the fluid type of the fluid of the glauconite-containing sandstone reservoir is determined according to the fluid identification value. The fluid types are divided according to the oil content of the reservoir. According to the technical scheme, the fluid identification value is accurately obtained through the constructed identification model, so that the fluid type of the glauconite-containing sandstone reservoir fluid is accurately determined according to the fluid identification value, the problem that the implementation cost is high when the reservoir fluid type is determined is solved, the fluid type division efficiency is improved, and the method is suitable for mass production. And a basis is provided for further research and explanation.

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.

The present invention relates to the technical field of control valve flow coefficient calculation, and specifically to a method for calculating the flow coefficient of a pseudoplastic power-law fluid control valve. First, based on the selected control valve and the type of pseudoplastic power-law fluid flowing through the control valve, basic process parameters are determined. Next, the Reynolds number, which is a key indicator for evaluating the flow characteristics of the fluid, is calculated using these basic process parameters and the constitutive equation of the pseudoplastic power-law fluid. Then, the equivalent friction coefficient is further calculated in combination with the Reynolds number and the basic process parameters to reflect the flow resistance of the fluid in the control valve. On this basis, the Reynolds number correction coefficient and the pressure drop are calculated by the Reynolds number and the equivalent friction coefficient, so as to more accurately describe the flow state of the fluid in the control valve.

The invention discloses a ship condenser high-energy additional fluid discharge structure design method, and relates to the field of energy power system surface type condenser high-energy fluid discharge. The problem that input high parameters (temperature, pressure and the like) cannot be compatible with an application scene in an actual small space due to the fact that an existing condenser structure design method only considers energy reduction level and does not consider optimization of structure parameters is solved. The fluid type is determined according to input fluid thermal parameters and condenser saturation parameters; determining the fluid energy level according to the inner diameter of the water / steam inlet and the fluid thermal parameters; the water / steam inlet position of the condenser body is judged according to the fluid deoxidization state or the fluid energy level; determining the type and parameters of the selected diffusion element according to the fluid energy level; evaluating the service life of the diffusion element, judging whether the service life of the diffusion element meets the service life requirement or not, and if so, ending; if not, the curvature and the thickness of the diffusion element are adjusted so that the diffusion element can meet the service life requirement. The method is mainly used for structural design of the condenser.

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.