205 results about "Fluid density" 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 transfer system component for internally measuring fluid density in real- time. The component may be a flange comprising a base having a first face and a second face, a primary fluid passageway extending through the base from the first face to the second face, a secondary fluid passageway extending through the base from the first face to the second face, and an outside wall, a portion of which is configured to operably engage with a measuring device and comprises a third opening. The primary fluid passageway may have a non-circular cross-section allowing the secondary fluid passageway to be parallel to the primary fluid passageway. The third opening may be in fluid communication with the secondary fluid passageway allowing the measurement device to measure fluid data such as fluid density via the secondary fluid passageway.

The invention discloses a method for measuring the flow velocity of fluid in a pipeline based on fluid medium parameter analysis, and relates to the technical field of fluid mechanics and fluid engineering. In order to solve the problems that in the prior art, flow velocity measurement data acquisition node arrangement and operation environment analysis of fluid in a pipeline are insufficient, the robustness of a measurement result is reduced, and the accuracy and reliability of flow velocity measurement are affected due to dependence on a single measurement model. Characteristic parameters such as fluid density and sound velocity are calculated and dynamically input into the flow velocity calculation model, real-time changes of the fluid parameters are comprehensively considered, the accuracy of the flow velocity measurement result is improved, the relation between the flow velocity and the sound wave propagation time difference is accurately established, the calculation result is compared with the flow velocity characteristic value and trend of historical data, and the accuracy of the flow velocity measurement result is improved. And the calculation precision of the flow velocity calculation model is evaluated based on the verification result, so that the adaptability, robustness and economy of the method are remarkably enhanced while the flow velocity measurement precision is improved.

The invention discloses a dynamic blockage management system and method for an underground water recharge well. The system comprises a monitoring and acquisition module, a data processing and risk assessment module, a flow rate adjustment optimization and dynamic feedback module and a storage and remote management module. The method comprises the following steps: monitoring key parameters such as water flow rate, suspended particulate matter concentration, fluid density and temperature and the like in a well injection process in real time, and carrying out data preprocessing; deriving a comprehensive blockage risk index calculation formula based on the key parameters, and comparing with a set threshold to judge whether flow velocity adjustment is triggered or not; by analyzing the relationship among the blockage risk, the pressure loss and the injection amount in real time, an objective function is constructed to seek an optimal solution; the well injection flow velocity is dynamically adjusted based on the solved optimal flow velocity and is dynamically fed back; and carrying out data storage and remote management. The device can dynamically adjust the injection flow rate, remarkably improve the injection efficiency, reduce the maintenance cost, and effectively manage and reduce the physical blockage problem in the underground water recharge process.

The invention relates to the technical field of parameter optimization, in particular to a data-driven hydraulic parameter real-time optimization method and system, and the method comprises the steps: obtaining drilling multi-source heterogeneous data, and carrying out the cleaning and multi-modal space-time alignment fusion, and generating a standardized multiphase flow parameter; inputting a pre-trained multiphase flow transient model through a data-model combined driving mechanism, dynamically correcting fluid density distribution and phase change parameters, and outputting a transient simulation result matched with a drilling working condition in real time; and determining hydraulic parameters to be optimized based on a simulation result, and generating a real-time optimization scheme of optimal displacement, throttling pressure and well killing parameters by combining wellbore pressure constraint and a multi-objective optimization function and adopting an adaptive particle swarm optimization algorithm for iterative calculation. According to the method, multi-source data space-time alignment and model dynamic correction are achieved, transient simulation precision is improved through a combined driving mechanism, and an optimal hydraulic parameter scheme meeting wellbore safety constraints can be generated by combining an adaptive optimization algorithm.

The invention discloses a remote monitoring management method for a municipal water supply and drainage pipe network system, which relates to the technical field of water supply and drainage monitoring and comprises the following steps of preparation before monitoring, system erection, construction of a central data processing system, data acquisition, data analysis and obtaining of real-time flow Q according to data acquired by sensor equipment. The method comprises the following steps: calculating by using a pressure loss algorithm to obtain a pressure loss amount delta S, carrying out comprehensive evaluation, obtaining a comprehensive score A by using a pipe network comprehensive evaluation algorithm in combination with a real-time flow Q and the pressure loss amount delta S, and storing data, and has the characteristics that a pipeline material influence coefficient and a pipeline resistance coefficient are added, and fluid density and a friction coefficient are introduced when the pressure loss amount is calculated; and finally, a comprehensive score is obtained through a pipe network comprehensive evaluation algorithm, the operation quality of the drainage pipe network can be comprehensively evaluated, the pipe network pressure is automatically adjusted according to the pressure adjustment amount when an emergency occurs, and the problem deterioration is avoided.

The invention discloses a two-phase flow relative permeability curve boundary processing method and system based on a lattice Boltzmann method, and the method comprises the steps: calculating the average density of an inlet boundary fluid, calculating the pressure difference between an inlet and an outlet, and then calculating the volume force; solving the velocity and density of the fluid by using a lattice Boltzmann method; correcting the volume force according to the fluid velocity to ensure that the inlet flow velocity is consistent with a set value; and updating the velocity distribution of the fluid according to the corrected volume force and fluid density so as to optimize and perfect the simulation of the steady-state relative permeability curve. The method has the advantages that by converting the speed-pressure boundary condition into the periodic boundary condition in the volume force format, the change of the boundary pressure and the injection flow velocity can be accurately simulated when the relative permeability curve is obtained through the steady-state method, and the inlet flow velocity is kept constant, so that the calculation precision of the relative permeability curve is improved.

The invention discloses a water hammer analogue simulation method and device for fracturing, and belongs to the technical field of oil and gas reservoir fracturing exploiting.The simulation method comprises the steps that a simulated shaft is determined; establishing a water hammer continuity equation and a water hammer motion equation based on the water head, the flow, the fluid density and the like; establishing a water hammer equation set by combining a liquid elastic equation combination, and solving to obtain a distribution equation of the water head, the flow velocity and the density; establishing a relational expression of fluid pressure, density and flow, and establishing a water hammer equation set in parallel to obtain a water hammer simulation model; initial conditions and boundary conditions are set, and a curve of water hammer pressure changing along with time is obtained through fitting. The device comprises a memory for storing a computer program and a processor, wherein the program comprises the steps corresponding to the method. According to the method, the water hammer pressure in the fracturing process can be more accurately simulated, developers are helped to analyze the fracturing effect by using the water hammer pressure in the fracturing process, so that fracturing parameters are optimized, a better fracturing effect is obtained, and efficient development of unconventional oil and gas resources is promoted.

The invention discloses a thickener dosing control method and system, and relates to mineral processing. The method comprises the following steps: acquiring concentration values measured by an ith concentration sensor at different depths at a moment t; obtaining the turbidity T of the overflow water, the effective viscosity of the overflow water or underflow, the volume fraction of fine particles and the volume fraction of coarse particles in the overflow water, the Zeta potential of the feeding end, the Zeta potential of the overflow end, the time derivative of the Zeta potential of the overflow end, the equivalent diameter d of the particles, the density of the particles, the density of the fluid and the viscosity of the fluid; calculating the effective settling velocity of the particle swarm; carrying out online correction on the effective settling velocity by utilizing a least square method or a Kalman filtering algorithm; performing time lag correction on the concentration values at different depths by using the corrected effective settling velocity; correcting the turbidity T of the overflow water according to the corrected concentration profile; respectively calculating a flocculant dosing rate and a coagulant dosing rate; according to the invention, accurate cooperative control of the dosing rate of the flocculating agent and the coagulant is improved through the artificial intelligence model.

The invention relates to the technical field of methods for obtaining formation pressure through oil drilling, in particular to a method for obtaining formation pressure based on wellbore pressure difference and gas logging total hydrocarbon response characteristics, which comprises the following steps of: collecting and arranging logging data, logging gas logging total hydrocarbon data, drilling fluid density data and the like after three or more drilled reference wells in the same block are drilled; calculating the stratum pressure equivalent density of a reference well and the well bottom pressure difference equivalent density of mudstone sections with different burial depths according to the data, drawing a well bottom pressure difference-logging gas logging total hydrocarbon intersection trend chart, reading corresponding well bottom pressure difference equivalent density delta P coordinate data according to the trend chart, and calculating the well bottom pressure difference equivalent density delta P coordinate data according to the well bottom pressure difference-logging gas logging total hydrocarbon intersection trend chart. And finally calculating the stratum pressure equivalent density of the stratum mudstone section of the target well. According to the method, the drilled reference well and the positively-drilled target well which are located in the same block serve as processing objects, the formation pressure calculation method based on logging information and the wellbore pressure difference are combined with the gas logging total hydrocarbon response characteristics, the formation pressure of the positively-drilled target well is accurately obtained while drilling, and the method has the advantages of timeliness and accuracy.

A method of wellbore operations for identifying sample fluid density and viscosity. The sample fluid is collected from a formation, and acoustically irradiated in a flow cell. Acoustic reflections are collected and analyzed to obtain a sound speed of the sample fluid and a value for the slope of the decay rate of an acoustic signal reverberating within a wall of the flow cell, which is in physical contact with the transducer. The fluid temperature, pressure, and the sound speed of the flow cell material may also be measured. The sample fluid density and viscosity are estimated from equations derived by a regression performed on a set of training data, which was generated from testing the flow cell with fluids having known densities, viscosities, or other characteristics.

The present invention relates to a metallic fluid tube (100) for a fluid connection arrangement (300) comprising: a metallic tube wall (101) having an inner tube wall (103) which defines an interior space (105) of the fluid tube (100), and having an outer tube wall (107) which faces away from the interior space (105) of the fluid tube (100) and towards an exterior space (109) of the fluid tube (100), wherein the tube wall (101) has a tube end (113) with a tube opening (115) which connects the interior space (105) of the fluid tube (100) with an exterior space (109) of the metallic fluid tube (100), wherein the tube wall (101) has a raised section (117) which surrounds the outer tube wall (107) and is spaced apart from the tube end (113), wherein the The outer surface of the pipe wall (107) has a circumferential sealing geometry (119),which is designed to provide a fluid-tight connection between the metallic fluid tube (100) and another fluid-carrying component (301) of the fluid connection arrangement (300), and wherein the circumferential sealing geometry (119) extends on the outside of the tube wall (107) from the raised section (117) to the tube end (113), and wherein the circumferential sealing geometry (119) has rotary grooves (121) which extend along a groove extension direction (123), wherein the groove extension direction (123) is transverse to a longitudinal extension direction (111) of the fluid tube (100).

The invention provides a wet inherent frequency measuring method for a ship with a liquid tank, and relates to the technical field of ship manufacturing, and the method comprises the steps: respectively calculating a total structure mass matrix and a total container mass matrix of a target ship based on a whole ship finite element model; and adjusting the total structure mass matrix to obtain a first total structure mass matrix. And taking the mass matrix of the container unit in the first total structure mass matrix as a to-be-superposed mass matrix, and superposing the total container mass matrix and the to-be-superposed mass matrix to obtain a total on-board mass matrix. And determining a wet surface unit and a liquid tank unit in the whole ship finite element model. A first attached water mass matrix is determined based on the external fluid density using a boundary element method. A second attached water mass matrix is determined based on the internal fluid density using a boundary element method. And determining an overall mass matrix, determining the wet inherent frequency of the target ship by adopting a free vibration equation, considering the influence of external and internal fluids on free vibration, and improving the accuracy of the wet inherent frequency.

The invention provides an electromagnetically-excited high-temperature liquid metal throttling flow measurement system and method, and belongs to the technical field of flow measurement. The method comprises the steps that direct current is connected to an electromagnetic excitation coil, and a direct-current magnetic field is generated around a non-metal pipeline; the magnetic field enables the liquid metal in the pipe to generate a throttling effect, so that the flow velocity is reduced to generate differential pressure; a differential pressure detection module is used for detecting the differential pressure of the liquid metal, a temperature sensor is used for detecting the temperature of the liquid metal in the pipe, and the flow coefficient is corrected; calculating a relational expression between the flow velocity and the flow of the liquid metal according to a Bernoulli equation; and the fluid density of the liquid metal is subjected to temperature compensation correction through the temperature and is substituted into the relational expression of the flow velocity and the flow of the liquid metal. Due to the fact that the physical property (such as density) of the liquid metal can change along with the temperature change, the flow measurement result is directly influenced, temperature compensation is conducted on the flow of the liquid metal, the measurement error can be corrected, and more accurate flow data can be obtained.

The invention discloses a method for detecting the conveying condition of a silicon steel inhibitor in a pipeline, and the method comprises the steps: obtaining the fluid density, fluid viscosity and fluid transverse average flow velocity of the inhibitor in a target pipeline, and measuring the speed of particles in the fluid and the average diameter of the measured particles; wherein the particle velocity comprises a particle transverse velocity and a particle longitudinal velocity; calculating a blockage index based on a blockage index calculation formula; meanwhile, the precipitation degree of the inhibitor in the target pipeline is obtained, and trend comparison is conducted on the precipitation degree and the blockage index; if the trends are inconsistent, adjusting a correction coefficient in a blockage index calculation formula until the trends are consistent, and forming a corresponding table of the blockage index, the precipitation degree and the transverse average flow velocity of the fluid; determining an actual blockage index based on the corresponding table and the actual fluid transverse average flow velocity; and performing early warning on the precipitation condition of the inhibitor in the target pipeline by using the actual blockage index. According to the method, the precipitation degree of the inhibitor in the pipeline is represented through the blockage index, and early warning is performed.

The utility model relates to the technical field of petroleum drilling and production, in particular to drilling fluid on-line monitoring equipment which comprises a surge tank, a manual three-way ball valve, an anti-explosion pneumatic ball valve, an anti-explosion pressure transmitter, an overflow chamber, a drain pipe and an anti-explosion temperature transmitter. Fluid is pumped by a pump and guided into a surge tank, temperature measurement is carried out through an anti-explosion temperature transmitter, real-time temperature data are output, high-temperature alarm is carried out through linkage with an anti-explosion pneumatic ball valve, flow adjustment is carried out on the fluid through a manual three-way ball valve, and the fluid continuously flows upwards to an overflow port through the anti-explosion pneumatic ball valve and then overflows into an overflow chamber. And during measurement, the explosion-proof pneumatic ball valve is closed, the fluid in a measurement area is static, the output pressure is measured through the explosion-proof pressure transmitter, the density of the output fluid is calculated by adopting a formula, and the equipment can detect the fluid in real time and give a high-temperature alarm, is rapid in detection and high in efficiency, and is suitable for large-scale popularization and application. The device is suitable for various complex working conditions and fluids.

The invention discloses a tunnel dynamic risk early warning method and system based on an intelligent algorithm, and belongs to the technical field of tunnel safety early warning. Based on the external load data, the gas pressure, the soil pressure and the temperature data, calculating stress data of each part of the tunnel by using a structural mechanical model; calculating an effective gas diffusion coefficient based on the stress data and the temperature data; calculating a fluid dynamic pressure effect based on the stress data, the fluid density and the flow velocity data; and evaluating the safety risk of the tunnel, generating an early warning signal according to a preset risk threshold value, and triggering a risk early warning notification. According to the invention, the limitation of single data source or periodic detection in the traditional method is overcome. And the stress and the safety risk of the tunnel are accurately evaluated by combining a structural mechanical model, a gas diffusion model and fluid dynamic pressure effect calculation. Through a gradient elevator algorithm, the accuracy and reliability of risk prediction are improved by using historical and real-time data, and dynamic management of tunnel safety is realized.

The invention discloses a density measurement array and a method for inverting a three-dimensional flow field based on a fluid density field change rate. According to the method, a temperature sensing array comprising temperature probes and an array structure is constructed through a temperature sensor, the temperature probes are arranged with a speed measurement point as the center, and the distance range is unequal from the micron level to the meter level. The array structure can adopt various geometric forms such as a rectangle, a circle and the like. Modeling is carried out by measuring a space distribution field of temperature, combining with calibration of a flow velocity meter and utilizing the relation between the temperature distribution change rate and the flow velocity, so that flow velocity information is inverted. By integrating a plurality of arrays, multi-point measurement of a three-dimensional flow field can be realized. According to the method, high-precision flow velocity measurement can be realized in an environment without scattering particles, and the measurement accuracy is further improved through multi-parameter verification. The range of measuring the fluid scale is wide, and an innovative solution is provided for monitoring the fluid flow speed.

The invention discloses an offshore deep continuous foam liquid drainage gas production process pipe column and an operation method, the pipe column comprises a production sleeve, an oil pipe, a lower suspension packer, an upper suspension packer and a continuous oil pipe, a production packer and a top packer are sequentially arranged between the oil pipe and the production sleeve from top to bottom, the oil pipe is located above the production packer for punching, and the continuous oil pipe is located above the production packer for drilling. The lower suspension packer is arranged below the punching position, the upper suspension packer is arranged above the punching position, the upper suspension packer is connected with the lower suspension packer in a sealed mode through an inserting head, and the lower portion of the lower suspension packer is connected with the coiled tubing. A foam scrubbing agent channel from an oil pipe and sleeve annulus to an oil pipe and continuous oil pipe annulus is established through cooperation of multiple tools, the foam scrubbing agent is introduced into a deep shaft liquid accumulation well section below a production packer and above a production layer from the oil pipe and production sleeve annulus, and the fluid density of a shaft is reduced; the mixed fluid is discharged from the continuous oil pipe and the upper oil pipe, and continuous and stable discharging and mining of the gas well are achieved.

The invention discloses a method for predicting the erosion rate of a control manifold of an offshore oil and gas exploration well. The method comprises the following steps: constructing a support vector machine model; wherein the input parameters of the support vector machine model are the manifold diameter, the manifold bending angle, the fluid speed, the fluid density and the fluid viscosity, and the output parameter of the support vector machine is the maximum erosion rate of the well control manifold; optimizing penalty function coefficients and kernel function parameters of the support vector machine model by adopting a genetic algorithm to obtain an optimized support vector machine model; training the optimized support vector machine model to obtain a well control manifold erosion rate prediction model; and acquiring the manifold diameter, manifold bending angle, fluid velocity, fluid density and fluid viscosity of the to-be-predicted well control manifold, and inputting into the well control manifold erosion rate prediction model to obtain the maximum erosion rate of the to-be-predicted well control manifold. According to the well control manifold erosion rate prediction method provided by the invention, the maximum erosion rate of the well control manifold can be accurately predicted.

The invention discloses an integrated intelligent flow sensor and a dynamic compensation system and method thereof.The sensor is of an integrated flow channel structure, a flow sensor, a temperature sensor and a pressure sensor are integrated, and compact design and signal isolation are achieved; the system calls a fluid physical property database by synchronously collecting three-parameter signals, and dynamically calculates the fluid density based on real-time temperature and pressure data; according to the method, the volume flow under the original working condition is dynamically compensated, and the high-precision volume flow and the directly-output mass flow are obtained. Flow measurement is fundamentally upgraded into'multi-parameter-material flow 'conversion based on the physical principle, and high-precision measurement is still guaranteed when the fluid state fluctuates.

The invention discloses a water conservancy project pipeline quality detection method and system. The method comprises the following steps: acquiring water pressure dynamic data and ultrasonic detection data of a to-be-detected pipeline; calculating water pressure parameters of the pipeline through a water hammer effect model based on the water pressure dynamic data; performing time-frequency analysis on the ultrasonic detection data, and extracting ultrasonic parameters of pipeline defects, including reflection probability, signal segment time-frequency difference and echo correction probability; and performing weighted fusion on the water pressure parameter, the ultrasonic parameter and a preset pipeline damage threshold to generate a load parameter. A water pressure parameter formula of the pipeline is calculated through the water hammer effect model, parameters such as the fluid density rho, the pipe elasticity modulus E and the yield strength sigma are integrated, instantaneous impact of the water hammer pressure peak value on the pipeline is quantified, and compared with a traditional static model, the precision is effectively improved.

A method includes flowing, in a closed loop geothermal well residing in a target subterranean zone, a first heat transfer working fluid and flowing, in the geothermal well, a second working fluid from the surface inlet to the downhole location of the geothermal well. The second working fluid resides upstream of the first heat transfer working fluid. The second working fluid includes a fluid density greater than a fluid density of the first heat transfer working fluid. The method also includes circulating, in the geothermal well, the second working fluid pushing, with the second working fluid, the first heat transfer working fluid toward a surface outlet of the geothermal well. The method also includes collecting energy from the mobilized first heat transfer working fluid received at the surface outlet of the geothermal well.

The invention relates to a safety density window prediction method and device considering fluctuation pressure, a medium and equipment. The method comprises the steps that real-time drilling dynamic parameters of a target well are obtained; on the basis of the real-time drilling dynamic parameters, a steady-state fluctuation pressure prediction model is established in combination with a HZ-Ba fluid model, fluctuation pressure generated in a shaft under the current working condition is dynamically calculated through the steady-state fluctuation pressure prediction model, and the fluctuation pressure comprises excitation pressure and swabbing pressure; carrying out equivalent density conversion on the calculated fluctuation pressure, respectively superposing the calculated fluctuation pressure with a static formation pressure parameter, and updating and outputting a safe drilling fluid density window considering the influence of the fluctuation pressure in real time; the output safe drilling fluid density window considering the fluctuation pressure influence is applied to field drilling fluid density design, and the reasonability of a fluctuation pressure calculation model and the reliability of the safe drilling fluid density window are verified by monitoring whether falling blocks return from the ground or not and monitoring well diameter logging data in real time.

The invention relates to an offshore CCUS well building shaft temperature and pressure coupling calculation method which comprises the following steps: substituting an initial temperature and pressure profile of a shaft into a shaft drilling fluid density prediction model to obtain drilling fluid density, and substituting the initial temperature and pressure profile into a rheological property prediction model to obtain drilling fluid viscosity; fluid pressure in the drill stem and fluid pressure in the annulus are obtained; all nodes with shaft pressure prediction differences meeting the precision requirement are selected; the fluid temperature is updated through the temperature model and the fluid density of the node with the difference value meeting the precision requirement of the wellbore pressure prediction difference value of the node; according to the fluid with the updated temperature, adjacent nodes with the shaft pressure prediction difference meeting the precision requirement are selected; selecting nodes corresponding to all fluids of which the circulating flowing time in the shaft meets the preset time requirement from all nodes of which the shaft pressure prediction difference meets the precision requirement; and taking the temperature and the pressure of the node meeting the requirements as final wellbore temperature and pressure profiles.

Embodiments of the present application provide a simulation method and device for killing well, electronic equipment, storage medium and product. The method comprises: obtaining a killing well boundary matrix equation, wherein the killing well boundary matrix equation comprises different killing fluid densities and volumes corresponding to each killing fluid density; determining a first time length for killing fluid to reach the bottom of the simulated well drill string from the ground and a second time length for killing fluid to return to the ground from the bottom of the simulated well drill string through the annular space according to the obtained parameter information of the simulated well; and obtaining a third time length, and then determining the distribution data of the killing fluid with different densities in the drill string and the distribution data in the annular space according to the killing well boundary matrix equation, the first time length, the second time length and the third time length. The distribution data in the drill string and the distribution data in the annular space can be used to simulate the distribution state of the killing fluid with different densities in the well. The method improves the flexibility of the killing well simulation method.

The present application belongs to the technical field of bearing lubrication state monitoring, and particularly relates to a bearing lubrication state real-time monitoring method based on fluid dynamics model correction, which comprises the following steps: obtaining original vibration acceleration signals and running state data, performing variational modal decomposition on the original vibration acceleration signals to extract cavitation characteristic components; calculating a cavitation kinetic energy impact index according to the extracted cavitation characteristic components and the running state data; dynamically correcting the equivalent fluid density of lubricating oil according to the cavitation kinetic energy impact index and the contact area pressure of the bearing estimated from the running state data; solving the minimum oil film thickness of the lubricating oil film by using the corrected equivalent fluid density, and determining a lubrication safety margin index in combination with the temperature rise rate of the bearing. The present application overcomes the defect that the monitoring result is distorted due to the single-phase fluid assumption, and improves the accuracy of bearing lubrication state monitoring and early risk warning.

The invention discloses an oil-water interface depth determination method and related equipment, and relates to the technical field of oil-gas exploration, and the method comprises the steps: obtaining formation pressure test data and formation test data of a target oil-water system; fluid density under the formation condition is obtained according to the formation testing data, and the straight slope is obtained through calculation; the slope of the straight line is used as a constraint value, in combination with formation pressure test data, a straight line intercept is determined, fluid fitting lines are obtained, and the fluid fitting lines comprise a water layer fitting line and an oil layer fitting line; and determining the oil-water interface depth of the target oil-water system according to the intersection point of the water layer fitting line and the oil layer fitting line. According to the method, the fluid density under the formation condition is obtained by comprehensively utilizing the formation pressure test data and the formation test data, and the oil-water interface depth of the target oil-water system is accurately determined in combination with a scientific fitting analysis method.

The present application relates to a kind of downhole hold rate measurement method, downhole fluid interface and geometric distribution determination method, belong to oil and gas exploration technical field.The downhole hold rate measurement method utilizes multiple tuning forks distributed on flow cross section, realizes oil-water determination by comparing the size of fluid density collected by tuning fork with the size of preset oil-water density distinguishing threshold, realizes the representation of downhole fluid hold rate using the time proportion of oil / water collected by tuning fork, with the advantages of good universality, high measurement efficiency and high resolution.The downhole fluid interface determination method utilizes multiple tuning forks distributed on flow cross section to realize oil-water determination, identifies oil-water interface point according to oil-water alternative switching phenomenon, and determines horizontal well oil-water interface.The downhole fluid geometric distribution determination method utilizes multiple tuning forks distributed on flow cross section to realize oil-water determination, combines local oil hold rate calculation and tuning fork position distribution, and draws fluid geometric distribution diagram.