165 results about "Fluid density" patented technology

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 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 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.

The invention discloses a liquid pipeline looseness detection method, and belongs to the technical field of mechanical vibration measurement, and the method comprises the steps: 1, obtaining the density of a fluid in a pipeline, and obtaining a density compensation coefficient according to the density of the fluid; 2, collecting vibration data of the pipeline, and calculating a vibration coefficient according to the vibration data; 3, collecting the temperature of the pipeline joint, obtaining the relative humidity of the environment, and calculating the temperature difference between the current moment and the previous moment; 4, obtaining the displacement of the pipeline connecting piece in the axial direction of the pipeline at the current moment; step 5, calculating a total state value K; and step 6, judging pipeline looseness: when the total state value K is greater than a set threshold value, judging that the pipeline is loosened. According to the liquid pipeline looseness detection method, temperature and environment temperature data are combined, a more accurate fault early warning mechanism can be formed, the pipeline looseness situation can be detected before leakage occurs in pipeline connection, and the problem that hysteresis exists in existing leakage detection is solved.

The invention discloses a method for determining adsorption characteristics of pure component fluid in nanopores and a processor, and belongs to the technical field of oil-gas field development. The method comprises the following steps: determining the volume phase fugacity of a pure component fluid in a nanopore at a current temperature and a current pressure; determining a fluid region in the nanopore according to the fluid molecule diameter of the pure component fluid and the pore channel width of the nanopore; determining the fluid fugacity of each position in the fluid area according to the volume phase fugacity; determining the fluid density distribution of the pure component fluid in the nanopores according to the fluid fugacity; and determining the excess adsorption quantity of the pure component fluid at the current temperature and the current pressure according to the fluid density distribution. According to the method and the device, the excessive adsorption quantity of any pure component fluid in the nanopores at the current temperature and the current pressure can be determined, so that the time cost of the excessive adsorption quantity determination process is reduced.

The invention discloses a dynamic optimization method for drilling parameters of a high-sulfur-content stratum, and relates to the technical field of oil-gas field development. The method comprises the following steps that engineering parameters in the drilling process are obtained in real time; the engineering parameters comprise to-be-optimized drilling parameters and hydrogen sulfide concentration; the hydrogen sulfide escape risk index is calculated in combination with engineering parameters, in the formula, H2Srisk represents the hydrogen sulfide escape risk index, CHS represents the hydrogen sulfide concentration, rho represents the drilling fluid density, G represents the geological risk, and k1, k2 and k3 all represent weights. A dynamic optimization function is established and solved, and when the dynamic optimization function value is minimum, the corresponding drilling parameter combination is the optimal drilling parameter combination. According to the method, the escape risk of hydrogen sulfide can be greatly reduced, the mechanical drilling speed is increased, equipment corrosion and vibration are reduced, safety and efficiency are both considered, and the method adapts to complex working conditions and is suitable for various high-sulfur-content stratum drilling scenes.

The invention provides a system for calculating fluid density by using a state equation, and belongs to the field of chemical process simulation. The system is provided with a state equation calculation module which is used for calculating the density solution (real density solution or pseudo density solution) of the system by utilizing a state equation according to the set pressure, temperature and component composition of the fluid system. Wherein the calculation process uses a dual search algorithm to iterate the density until the pressure value or the temperature value converges, and comprises the following steps: dynamically selecting a search path by using local curvature information of a pressure-density function or a temperature-density function: when the curvature of the function meets a solvable condition, constructing a quadratic approximation model to approach a density solution; and when the function curvature does not meet the solvable condition, switching to a first-order approximation model, and determining a density extrapolation starting point in combination with a preset density extrapolation starting point slope threshold. And after the density extrapolation starting point is obtained, the module calculates a pseudo density value through an extrapolation method. The system does not need an analytical solution of a state equation or continuation of a complex field, and the solving efficiency is greatly improved.

The present disclosure provides a fluid property measurement apparatus and a fluid property online measurement method. The apparatus includes: a testing cylinder provided with a fluid inlet and a fluid outlet; a liquid stabilizing mechanism including a pre-liquid delivery structure and a gas delivery structure, the pre-liquid delivery structure including a defoaming tank and a detachable pipeline connected thereto, the detachable pipeline being connected to the fluid inlet, and the gas delivery structure including a gas passage capable of injecting gas into the testing cylinder; and a measuring mechanism including a mass detector connected to a bottom of the testing cylinder and a liquid level detector connected within the testing cylinder. The present disclosure solves the problem of online measurement of drilling fluid density in the technical field of fluid measurement.

The invention discloses a method for predicting the pressure loss of a radiant tube elbow. The method comprises the following steps: performing an experiment to obtain a pressure loss-speed experiment curve of a single radiant tube elbow; constructing a radiant tube elbow physical model, and calculating by using different flow models to obtain a pressure loss-speed calculation curve; comparing the pressure loss-speed experimental curve with the calculation curve, and determining a matched flow model; building radiant tube elbow physical models with different geometric parameters, and calculating corresponding data of different geometric parameters, flow velocity and elbow pressure loss based on the matched flow model; a pressure loss prediction relational expression is established, the pressure loss is a direct proportion function of the bend resistance coefficient and the fluid density, the pressure loss is a power function of the flow speed, and the bend resistance coefficient is a power function of the bending ratio and the bending angle of the bend; and fitting and determining a pressure loss prediction relational expression based on the corresponding data and predicting the pressure loss of the radiant tube elbow. The prediction error of the pressure loss of the radiant tube elbow can be reduced.

The invention discloses a rock physical model construction method, device and equipment, a medium and a product. The method comprises the following steps: determining a compaction factor according to porosity data and stratum thickness data; determining the elasticity modulus of the dry rock skeleton according to the mineral component content and the compaction factor; determining a fluid bulk modulus and a fluid density according to the water saturation data and the gas saturation data; determining a saturated rock elastic modulus according to the dry rock skeleton elastic modulus and the fluid volume modulus; determining the saturated rock density according to the fluid density and the rock matrix equivalent density, and further determining the longitudinal wave velocity and the transverse wave velocity of the saturated rock; and determining a rock physical model according to the longitudinal wave velocity and the transverse wave velocity. According to the technical scheme, the problem of poor reliability of rock physical modeling is solved, the compaction factor is introduced in the rock matrix elastic modulus determination process, the rock matrix elastic modulus considering the mechanical compaction effect is calculated, and the accuracy and effectiveness of the rock physical model can be improved.

An improved fluid transfer accuracy, information collection, and overall management. A system may utilize a pump to transfer fluid from a source to a target vessel, a meter for measuring an amount of fluid transferred, a density meter to detect actual fluid density, and a control unit to determine actual fluid transfer amount based on density. As an example, a fluid flow meter can be coupled with a flow conduit to determine fluid volume, along with the density meter to detect real-time density of transferred fluid. During a fluid transfer event, such as aircraft refueling, LPG fueling, or other refined fuels or valuable liquids, fluid volume can be converted to fluid weight in real-time based on actual density. The real-time fluid weight can be used to determine if a target fluid weight has been reached, and fluid flow can be shut off at the appropriate time.

The present application discloses a fluid density data analysis method and related equipment, which relate to the field of surveying technology. In the process of fluid density data analysis, the data credibility can be reflected and the reference value of the data analysis results can be improved. The fluid density data analysis method includes: performing logging operations based on a cable formation pressure test method to obtain depth data and pressure data; calculating a confidence value based on the depth data and the pressure data; comparing the confidence value with a confidence threshold; if the confidence value is greater than or equal to the confidence threshold, obtaining fluid density data based on the depth data and the pressure data; and drawing a fluid density chart based on the depth data, the pressure data, and the fluid density data.

The invention discloses a method for measuring the ground clearance of a wear-resistant block and a dredger, and relates to the technical field of dredgers. The method comprises the following steps: calculating the current acting force of a high-pressure nozzle on a wear-resistant block during operation of the dredger based on the fluid density of an operation area of the dredger and the flow and injection speed of the high-pressure nozzle during operation of the dredger; the current pulling force of the drag head on the wear-resisting block during operation of the dredger is obtained through the pulling pressure sensor; and inputting the self weight of the wear-resistant block, the fluid buoyancy of the dredger operation area, the current acting force and the current pulling force into a pre-trained ground clearance calculation model to obtain the current ground clearance of the wear-resistant block when the dredger operates. According to the technical scheme of the embodiment of the invention, the accuracy of calculating the ground clearance of the wear-resistant block is improved.