159 results about "Reservoir fluid" patented technology

The invention relates to an array electric imaging logging based reservoir oil-water identification method and system. Aiming at the resistivity distribution characteristics of mud-invaded formations, a 'five-parameter formation model' is established, which is adapted to the requirement for simulating the resistivity distribution characteristics of different mud types and different invaded formations, and is pioneering in the aspects of forward-inversion models and processing methods of array electric imaging logging; and based on a 'five-parameter inversion' method for array electric imaging logging, an operation of carrying out resistivity distribution profile reconstruction on mud-invaded formations is performed, which reflects the actual differences between different resistivity distribution characteristics or change rules of mud-invaded oil formations or water formations. The method has stronger practicability, and is pioneering in the actual application aspects of qualitative identification and quantitative calculation on reservoir fluid properties.

The invention relates to the technical field of oil and gas geophysical exploration, and particularly discloses a tight sandstone gas reservoir fluid mobility gradient attribute prediction method and system.The method comprises the steps that a reflection coefficient expression containing a fluid mobility item is constructed, and a formula for calculating fluid mobility through frequency dispersion attributes is deduced; constructing a fluid mobility gradient attribute related to the frequency and the incident angle of the seismic wave; the method comprises the following steps: establishing a double-pore rock physical model, generating a synthetic seismic record, applying frequency variation AVO inversion to the synthetic seismic record, and extracting a bulk modulus dispersion attribute and a shear modulus dispersion attribute; and calculating the fluid fluidity changing along with the frequency and the incident angle, and calculating the gradient attribute of the fluid fluidity based on a gradient attribute calculation formula and the fluid fluidity. According to the method, seismic wave frequency dispersion and attenuation response caused by permeability and gas saturation are fully utilized, the seismic gradient attribute of the fluid fluidity and the calculation method are constructed, and high-precision prediction of the fluid fluidity by applying seismic signal elasticity and frequency dispersion rock physical information is realized.

The invention relates to the technical field of oil and gas field development, in particular to an ultra-deep gas well production string multi-mode leakage simulation experiment device and method. According to the technical scheme, the outer side of a shaft temperature and pressure coupling simulation system is connected with a reservoir gas supply simulation system, the middle of the shaft temperature and pressure coupling simulation system is provided with a multi-mode leakage simulation assembly, the lower end of a production oil pipe is connected with a reservoir-shaft coupling connector, and the upper portion of one side of a layered sand filling seepage tank of the reservoir gas supply simulation system is connected with a confining pressure loading unit through a pipeline; the lower portion of the layered sand filling seepage tank is connected with a reservoir fluid supply unit, and the outlet end of the layered sand filling seepage tank is connected with a reservoir-shaft coupling connector through a pipeline. The experimental device has the beneficial effects that the experimental device for coupling the reservoir and the shaft is constructed, and the multi-mode leakage simulation assembly is adopted to realize body perforation leakage simulation and screw thread sealing failure simulation, so that the simulation of the ultra-deep gas well under complex working conditions is realized, and a scientific basis and a technical support are provided for leakage prevention and control of a production string of the ultra-deep gas well.

The invention discloses a displacement potential energy gradient oriented injection-production reconstruction optimization method between fracturing segments, and relates to the technical field of oil and gas field development. The method comprises the following steps: firstly, establishing an oil reservoir three-dimensional numerical model according to oil reservoir interpretation data, simulating in an oil reservoir numerical simulator by using the oil reservoir three-dimensional numerical model to obtain a global pressure field and a fluid flow velocity change condition in the oil reservoir, constructing a fluid potential field model, and determining potential energy gradients among injection-production units; constructing an objective function and setting constraint conditions by taking the most balanced potential energy gradient distribution among all injection and production units in the fluid potential field model as an optimization objective, solving the objective function based on a particle swarm algorithm, and optimizing the horizontal well multi-stage fracturing inter-section injection and production scheme to obtain the optimal horizontal well multi-stage fracturing inter-section injection and production scheme. The control device is used for controlling the injection-production process device between the multistage seam sections of the horizontal well, quantitative characterization and active control of an oil reservoir fluid potential field are achieved, and a basis is provided for improving the injected fluid sweep volume and the crude oil recovery rate of an oil reservoir.

The invention discloses a high-pressure CO2 oil displacement micro-fluidic chip device which comprises an upper polar plate, a middle partition plate, a lower polar plate, a speed measurement module, a porous medium radial flow module and a liquid outlet module, the speed measurement module is arranged on the upper surface of the middle partition plate; the porous medium radial flow module and the liquid outlet module are arranged on the upper surface of the lower polar plate; the upper polar plate, the middle partition plate and the lower polar plate are sequentially stacked from top to bottom; the speed measurement module is connected with the porous medium radial flow module; and the porous medium radial flow module is connected with the liquid outlet module. According to the device disclosed by the invention, a pore throat structure in rock is simulated by constructing a micron-sized or even smaller complex flow channel, and the CO2 flooding crude oil flow characteristic and the CO2 distribution rule are simulated; a transparent visualization device structure is designed, and visualization of the action mechanism of the CO2 oil displacement system and the reservoir fluid distribution characteristics is guaranteed.

A reservoir fluid can be produced from a subterranean formation. The reservoir fluid can include water and hydrocarbons such as oil. It is oftentimes desirable to limit the amount of water that is produced, so a higher ratio of hydrocarbons can be produced. Portions of the subterranean formation can have an initial permeability to water. A relative permeability modifier (RPM) package including a surfactant and a polymer can be used in these portions to restrict or prevent water from being produced. The relative permeability modifier package can increase the hydrophobicity of the portion that allows the hydrocarbons to flow through while substantially limiting the amount of water. The relative permeability modifier can coat the surfaces of substances in the formation whereby the permeability to an aqueous fluid is reduced from the initial permeability. The formation can be a high-temperature formation of 230° F. (110.0° C.) or greater.

This invention belongs to the field of seismic reservoir prediction and intelligent geophysical interpretation technology, specifically involving an intelligent reservoir prediction method for suppressing strong interference anomalies. The method first preprocesses seismic data and uses the generalized S-transform to obtain the time-frequency spectrum of the seismic signal. Then, based on the frequency component variation relationship, fluid flow properties are constructed to enhance reservoir fluid response characteristics and suppress strong response anomaly interference from non-reservoir areas. Furthermore, seismic data and fluid flow properties are jointly input to construct an intelligent reservoir prediction network based on a residual U-Net structure. Multi-scale feature extraction and fusion are achieved through an encoder-decoder structure and skip connections. Finally, the probability prediction result of the reservoir is output. This method can effectively fuse seismic structural information and fluid flow property information, improving the accuracy and stability of reservoir prediction under complex geological conditions, and has good generalization ability and application value.

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 application discloses a kind of visualization methods for microcosmic action mechanism of steam displacement heavy oil, which comprises: obtaining the porous structure information of rock sample;According to the structure information of rock sample, design pore network structure and make microfluidic chip;Build steam displacement heavy oil visualization implementation system, and adopt steam displacement heavy oil visualization implementation system to collect the phase distribution and temperature distribution of microfluidic chip in displacement process;Boundary extraction is carried out to experimental picture, and the dynamic change process of each phase in displacement process is obtained and the interaction relationship with temperature distribution change is obtained.The application designs pore network chip according to the pore structure information of rock sample, obtains the phase distribution and temperature distribution in displacement process, and is used to study the microcosmic phase distribution characteristics and temperature distribution characteristics of fluid in heavy oil reservoir reservoir, and then the microcosmic mechanism of reservoir fluid movement is explored, so as to provide a practical visualization method for the research of steam drive oil mechanism.

The invention discloses a hydrate-containing sediment exploitation fluid-solid output prediction method. The method comprises the following steps: carrying out reservoir mud and sand particle stress analysis; based on the moment balance principle, a judgment criterion of reservoir sand falling and migration under the hydraulic condition is established, and a reservoir mud and sand particle migration mathematical model is established in combination with reservoir mud and sand particle mass conservation; constructing a multi-field coupling model of hydrate reservoir fluid-solid output; discretizing the multi-field coupling model by adopting an unstructured grid technology, and carrying out decoupling solution by adopting an alternating iteration method; and on the basis of decoupling solution result data, a nonlinear mapping relation from the characteristic parameters to the gas production rate and the sand production rate is established by utilizing a deep learning model, a fluid-solid output prediction model is established, and accurate prediction of the gas production rate and the sand production rate is realized on the basis of the fluid-solid output prediction model. According to the method, the interaction mechanism between the gas production behavior and the sand production behavior of the reservoir can be disclosed more accurately, so that the fluid-solid production rule of the hydrate reservoir can be predicted more accurately.

The present application relates to oil and gas geophysical exploration technology field, specifically disclose a kind of tight sandstone gas reservoir fluid mobility gradient attribute prediction method and system, the method includes constructing fluid mobility term's reflection coefficient expression, and deduce the formula for calculating fluid mobility using dispersion attribute, construct and frequency and seismic wave incidence angle related fluid mobility gradient attribute;Establish double-pore petrophysical model, generate synthetic seismogram, apply frequency-variable AVO inversion to the synthetic seismogram, extract bulk modulus dispersion attribute and shear modulus dispersion attribute;Fluid mobility changing with frequency and incidence angle is calculated, based on gradient attribute calculation formula and fluid mobility, fluid mobility gradient attribute is calculated.The present application makes full use of the response of the seismic wave dispersion and attenuation caused by permeability and gas saturation, constructs the seismic gradient attribute and calculation method of fluid mobility, realizes the high-precision prediction of fluid mobility by applying the elastic and dispersion petrophysical information of seismic signal.

A conveyor for a sucker rod pump, for deployment downhole within a passage defined by an inner surface of a reservoir fluid conductor that is emplaced within a wellbore extending into a subterranean formation, for effecting production of reservoir fluids, comprising. The conveyor includes a rod configuration, and a guide configuration. The guide configuration is coupled to the rod configuration, and is defined by at least one protuberance. The protuberance defines an air foil shape.

The invention provides a rock water content obtaining method based on one-dimensional nuclear magnetism, pyrolysis and extraction experiments, and relates to the field of geological prospecting, the method comprises the following steps: extracting hydrocarbon-containing fluid in a rock sample by using an oil-water amphiphilic solvent; carrying out a rock pyrolysis experiment on the sample after extraction to obtain an extraction advance value, an extraction advance value and a post-extraction value, and calculating the hydrocarbon content of the sample; carrying out a one-dimensional nuclear magnetic resonance experiment of the pre-extracted sample to obtain a pre-extracted nuclear magnetic resonance signal; carrying out a one-dimensional nuclear magnetic resonance experiment on the extracted sample to obtain an extracted nuclear magnetic resonance signal; acquiring the fluid content of the sample according to the nuclear magnetic resonance signal before extraction and the nuclear magnetic resonance signal after extraction; and calculating the water content of the sample according to the hydrocarbon content and the fluid content. The technical scheme of the invention is suitable for reservoir evaluation, resource quantity calculation, reservoir fluid monitoring in the development process and other scenes.

A method of determining a validated vug interpretation log for performing a reservoir fluid flow simulation is disclosed. The method including obtaining a set of well logs from a wellbore, where at least one of the set of well logs may be used as a validating resistivity log, producing an initial vug interpretation log based on at least one of the well logs, and determining a scaled resistivity log from the validating resistivity log The method further includes determining a validated vug interpretation log based, at least in part, on the scaled resistivity log and the initial vug interpretation log; and performing a reservoir fluid flow simulation based, at least in part, on the validated vug interpretation log.

The application discloses a kind of fluid identification method and system of water-saturated hydrogen index contrast method, calculate reservoir matrix porosity;Electric imaging and double lateral data are combined to calculate rock fracture porosity, and sum matrix porosity to total porosity;Assume that bedrock reservoir pore is water-saturated, select the dynamic skeleton neutron value of the dense layer section of lowest porosity, high resistivity dynamic skeleton as fixed skeleton value, calculate the dynamic skeleton neutron value of the purpose layer in combination with total porosity;According to dynamic skeleton neutron value, calculate water-saturated hydrogen index of research interval;Water-saturated hydrogen index is compared with neutron actual logging value to calculate neutron difference value;In combination with gas production test data, the relationship between acoustic time difference and neutron difference value and the change relationship between matrix porosity and neutron difference value are analyzed using neutron difference value, and the relationship chart of quantitative identification gas-water layer is obtained.The method eliminates the influence of anisotropy, fracture occurrence and the like of bedrock lithology, highlights the characteristics of reservoir gas layer, and can more accurately identify the properties of reservoir fluid.

The invention discloses a complex reservoir gas-bearing prediction method and device, electronic equipment and a medium. The method comprises the following steps: constructing a low-frequency velocity model based on seismic division; performing convolutional coding and decoding of the seismic data according to the unsupervised closed-loop convolutional network to obtain sparse representation of the seismic data; and based on the semi-supervised closed-loop convolutional network, intelligent inversion of sensitive parameters of the deep reservoir is carried out, and reservoir gas-bearing prediction is realized. According to the method, fluid prediction under the condition of few wells is realized, the method is a demand for complex reservoir exploration situation and a key step for well position arrangement, and the method is of great significance to complex reservoir fluid prediction and subsequent treatment.

The invention discloses a tight oil reservoir depletion type development wave and region evaluation device and method. The device comprises a tight oil reservoir simulation system, a horizontal well system, a pressure monitoring system and a production system, the tight oil reservoir simulation system comprises a reservoir simulation device and a fluid injection device which are connected. The reservoir simulation device can be filled with sand grains in a layered manner so as to simulate a target tight oil reservoir; the fluid injection device is used for injecting simulated formation water and simulated formation oil; the horizontal well system comprises a plurality of horizontal wells; each liquid production pipe is connected with a corresponding horizontal well outlet and is connected with a produced liquid metering device; the pressure monitoring system comprises a signal processor, a pressure sensor and a plurality of pressure probes; and the plurality of pressure probes are arranged in the reservoir simulation device. According to the device, the distribution rule of the sweep area can be identified according to the pressure change, the recovery ratio corresponding to the sweep area can be obtained, and therefore sweep area evaluation is achieved through physical simulation, and production guidance is provided for depletion type development of tight oil reservoirs.

This invention relates to the field of petroleum exploration and development technology, and is a method and system for fluid property identification based on micro-fluorescence thin section technology. The method includes acquiring the micro-fluorescence thin section spectrum of a rock sample; obtaining the true fluorescence area under blue light and the true fluorescence area under ultraviolet light based on the micro-fluorescence thin section spectrum of the rock sample; substituting the true fluorescence area under blue light and the true fluorescence area under ultraviolet light into an extinction index model to obtain an extinction index; and comparing the extinction index with an extinction index evaluation standard to identify fluid properties. This invention establishes an extinction index for identifying reservoir fluid properties. Its extinction index model extracts the pair of sensitive parameters—fluorescence area under blue light and ultraviolet light—by utilizing the spectral variation characteristics between different crude oils and different proportions of water under micro-fluorescence thin section technology. This effectively solves the problem of reservoir fluid property identification, and the method can quantitatively identify reservoir fluid properties.

A kind of laboratory quantification permeation flow capacity device, comprising: displacement liquid filling bottle for filling displacement liquid, the top of displacement liquid filling bottle is erected with displacement liquid level gauge communicated with its cavity;Oil filling bottle for filling crude oil, the top of oil filling bottle is erected with crude oil level gauge communicated with its cavity;Permeation material holder, which includes holding cylinder, first push glass and second push glass are oppositely arranged in holding cylinder, the first push glass is fixedly connected relative to holding cylinder, the second push glass is axially movable relative to holding cylinder, glass gasket with aperture and permeation material fixed by glass gasket are arranged between first push glass and second push glass.The laboratory quantification permeation flow capacity device of the present application is simple and durable, and the operation method is simple, which provides test facilities for exploring the mechanism of reservoir fluid multi-effect synergistic oil displacement experiment, and enriches the test method for verifying the permeation capacity of permeation material.

The invention discloses a dolomitic mudstone reservoir fluid property determination method, device and equipment and a medium, and is applied to the field of exploration. The dolomitic mudstone reservoir fluid property determination method provided by the invention comprises the following steps: performing resistivity detection on a to-be-detected dolomitic mudstone reservoir to obtain a resistivity data set; determining a resistivity abnormal value according to the resistivity data set; determining a resistivity median according to the resistivity data set and the resistivity abnormal value; determining a reservoir space evaluation factor according to the resistivity median and the resistivity characteristic value; and comprehensively analyzing the reservoir space evaluation factor, the resistivity median and the resistivity characteristic value to determine the fluid property of the dolomitic mudstone reservoir to be detected. According to the method, the fluid property of the dolomitic mudstone reservoir to be tested is obtained by comprehensively analyzing and judging three groups of data including the obtained reservoir space evaluation factor, the resistivity median and the resistivity characteristic value, the problem that the fracture-cavity reservoir cannot be accurately evaluated by conventional logging information is solved, and effective and accurate evaluation of the reservoir space is realized.

There is provided a system for producing hydrocarbon material from a subterranean formation. The system includes a separator for separating gaseous material from reservoir fluid obtained from the subterranean formation. The system is configured to mitigate interference to the separation.

The invention discloses a reservoir fluid form identification method, device and equipment and a storage medium, and belongs to the technical field of oil and gas extraction. Based on the physical experiment data of the sample rock, a plurality of influence factors influencing the water layer resistivity and the oil layer resistivity can be accurately determined, so that the resistivity model (the first water layer resistivity model and the first oil layer resistivity model) can be established through multi-factor fusion, and the accuracy of the established resistivity model can be improved. The logging sensitive curve is determined on the basis of the first water layer resistivity model and the first oil layer resistivity, so that the resistivity model can be determined in a mode of combining physical experiment data and conventional logging information; therefore, the accuracy of the determined resistivity model (the second water layer resistivity model and the second oil layer resistivity model) is improved, and the accuracy of fluid property identification based on the resistivity model (the second water layer resistivity model and the second oil layer resistivity model) is further improved.

This application provides a numerical simulation method, apparatus, and storage medium for asphaltene deposition unblocking, belonging to the field of oil and gas field development technology. The method includes: constructing a thermodynamic component model containing asphaltene based on reservoir fluid composition; calculating oil-solid phase equilibrium conditions using equations of state; setting a critical mole fraction for asphaltene precipitation in the oil phase, where precipitation occurs when the actual mole fraction is greater than or equal to the critical value; setting reaction paths for precipitation and unblocking reactions; establishing a porosity-permeability coupled evolution model, where porosity decreases linearly with solid deposition, and permeability decreases power-lawically with decreasing porosity; embedding the above model into a reservoir numerical simulator, and dynamically updating the asphaltene concentration, solid deposition, porosity, and permeability parameters of each grid through time-step numerical solutions.

The invention discloses a method for improving complex oil reservoir discovery and application, on the basis of obtaining detailed well drilling and logging data and well logging interpretation data, evaluation of reservoir rock wettability is innovatively introduced, and the key parameter provides a unique view angle for understanding reservoir fluid behaviors and predicting oil and gas distribution. Through comprehensive analysis of the information, the method can more accurately describe the contour of the complex oil reservoir and identify a potential high-quality reservoir, so that the discovery probability of the complex oil reservoir is remarkably improved, in addition, the importance of dynamically adjusting a swabbing liquid drainage mode and parameters is emphasized, and the method has a good application prospect. It is ensured that flexible response can be carried out according to real-time feedback in the exploration process, and the exploration effect is further optimized. Due to the flexibility and adaptability, the method can show a good application effect in different types of complex oil reservoirs under different geological conditions, finally, according to the optimized swabbing result, the development value of an exploration target layer can be scientifically and objectively judged, and powerful data support and theoretical basis are provided for decision makers.

The application relates to a sliding sleeve completion pipe string flow skin calculation method and system, which is characterized by comprising the following steps: according to the pressure distribution characteristics in the flow process of the sliding sleeve completion pipe string, the flow area of the reservoir fluid is divided; the boundary of the linear flow area in the flow area is determined based on the geometric boundary; the boundary of the radial flow area in the flow area is determined based on the geometric boundary and the roundness; and the skin coefficient caused by the near wellbore zone of the sliding sleeve completion pipe string is determined according to the pressure drop difference of the reservoir fluid through the sliding sleeve completion pipe string and the open hole well based on the divided flow area and the determined boundary. The application can be widely applied in the technical field of completion pipe strings.

The invention provides a rapid method for evaluating the yield increasing effect and economical efficiency of underground electric heating of a horizontal well, and belongs to the technical field of oil and gas field development. Comprising the following steps that geological reservoir parameters of a target oil field, thermophysical parameters of rock fluid, temperature and pressure monitoring data and oil well parameters of a target oil well are collected; improving a horizontal shaft-oil reservoir heat transfer simulation device; determining the influence of oil reservoir fluid parameters and oil well parameters on the heating condition; carrying out sensitivity analysis on oil reservoir fluid parameters and oil well parameters which influence the heating condition; respectively establishing two-dimensional curve charts of the relationship between the influence parameters and the oil increase percentage and the relationship between the influence parameters and the input-output ratio; and determining the underground electric heating yield increasing effect and economical efficiency evaluation indexes of the horizontal well. According to the method, based on the formation temperature and pressure conditions and the reservoir temperature distribution rule of horizontal well underground electric heating in the formation liquid supply state, the influence of different factors on the oil increasing percentage and the input-output ratio before and after electric heating is considered, and an important basis is provided for productivity prediction and effect evaluation of horizontal well underground electric heating.

A device may include a remote pump jack configured to lift reservoir fluids from underground. A device may include an oil tank connected to the remote pump tank, the oil tank being configured to store the reservoir fluids and allow the reservoir fluids to separate into one or more of oil and a headspace vapor. A device may include a pneumatic gas booster connected to the oil tank, wherein the pneumatic gas booster is configured to draw in the headspace vapor during a vapor recovery operation. A device may include the pneumatic gas booster being connected to a liquid nitrogen tank that provides a motive gas to the pneumatic gas booster such that as the pneumatic gas booster draws in the headspace vapor, the motive gas furnishes a stable drive pressure during the vapor recovery operation.

A computer-implemented method that enables dew point pressure prediction using isothermal constant composition expansion and artificial intelligence is described herein. The method includes obtaining constant composition expansion data of a reservoir fluid, and predicting saturation pressures for the reservoir fluid at the constant composition expansion data points using a trained machine learning model selected from multiple machine learning models that are trained using data from a generated constant composition expansion library. The method also includes determining a central tendency of the predicted saturation pressures to obtain a final saturation pressure corresponding to the constant composition expansion data for the reservoir fluid. In examples, the final saturation pressure is a dew point pressure of the reservoir fluid

The invention discloses a recording and measuring coupled mesozoic volcanic reservoir fluid quantitative identification method, which comprises the following steps: determining fluid properties by using test data, selecting logging data and logging data reflecting the fluid properties, and screening out sensitive parameters related to the fluid properties by using a Pearson correlation analysis method; carrying out significance analysis on the sensitivity parameters, and screening out the sensitivity parameters without multiple collinearity; normalizing the sensitivity parameters, and calculating the weight of the sensitivity parameters by using a grey relational degree method; based on the weight of each sensitive parameter, constructing a quantitative evaluation index of the recorded and measured multi-parameter coupling fluid; and establishing a quantitative evaluation standard of the recorded and measured multi-parameter coupling fluid in combination with the test data and the quantitative evaluation index. According to the method, the comprehensive response of logging is combined, multi-parameter coupling is utilized to reflect different fluid properties, operation is easy, application and popularization are easy, and the method is suitable for rapid identification of fluid properties on site.

This invention discloses a method for evaluating the influencing factors of proppant breakage rate under reservoir conditions, comprising: S1: using an electric vibrating sieve and a sieve to screen the original proppant sample by particle size, testing the bulk density of the original proppant sample, and dividing the original proppant sample into two parts, I and II, each part being weighed according to a formula; S2: proppant breakage rate test under reservoir closure pressure conditions; S3: proppant breakage rate test under reservoir temperature conditions; S4: proppant breakage rate test under reservoir fluid environment conditions; S5: proppant breakage rate test under reservoir environment conditions; S6: calculating the processed proppant breakage rate according to the formula and analyzing the influence of influencing factors on the proppant breakage rate. The breakage rate testing and analysis method in this invention analyzes the degree of influence of influencing factors on the proppant breakage rate under reservoir conditions, providing experimental guidance for a more in-depth study of the proppant breakage rate mechanism.