69 results about "Petroleum exploration" patented technology

This disclosure relates to the field of petroleum exploration and development technology, and in particular to a method and system for determining bottom water intrusion characteristics. The method includes: determining the water permeability and the correlation coefficients between the matrix and fractures in a target block of a fractured sandstone gas reservoir; establishing and solving a mathematical model for cylindrical bottom water intrusion in a single well of the fractured sandstone gas reservoir based on the determined water permeability and the correlation coefficients between the matrix and fractures, obtaining a pressure function representing the difference between the original water pressure and the pressure at any point within the gas reservoir; using the obtained pressure function, determining the dimensionless bottom water intrusion volume; and determining the cylindrical bottom water intrusion characteristics of the dimensionless bottom water intrusion volume with respect to dimensionless time based on the determined dimensionless bottom water intrusion volume. By establishing a mathematical model of bottom water intrusion and calculating the cumulative water intrusion volume, the bottom water intrusion characteristics are determined, enabling an understanding of the entire dynamic process of bottom water intrusion in the reservoir.

This invention belongs to the field of petroleum exploration and discloses a quantitative characterization method for structural fracture parameters based on the coupling of the minimum energy consumption and minimum action principle. To overcome the shortcomings of existing technologies in achieving quantitative prediction of structural fractures from qualitative description, this invention first calculates the energy consumption of fracture rupture through rock mechanics experiments; then, it couples the minimum energy consumption principle and the minimum action principle to establish a rock fracture criterion; based on this, it derives and establishes quantitative characterization models for fracture aperture, volumetric density, and linear density; subsequently, it constructs a heterogeneous mechanical parameter volumetric model and performs elastoplastic geostress field simulation; finally, it achieves batch prediction of structural fracture parameters through programming, and verifies the reliability of the prediction results using core, imaging logging, and production dynamic data. This invention, starting from the physical essence of energy distribution and path selection, provides a unified theoretical framework for rock fracture and significantly improves the prediction accuracy of fracture "sweet spots."

This application relates to a method for determining remaining shot pairs, a method for determining the vacancy and occupancy of geophysical equipment, electronic equipment, and a method for rolling operation of geophysical equipment, relating to the field of seismic data acquisition technology in petroleum exploration. The method for determining remaining shot pairs includes: determining shot point data for all shot points to be excited in the scheme, geophone point data for all geophones in the scheme, and shot-geophone relationship data based on work area data and acquisition construction scheme; determining the shot pair values ​​of geophones falling within a preset acquisition construction template range based on the above data; and determining the remaining shot pairs of geophones based on the shot pair values ​​of the geophones and the information of shot points already excited within the acquisition construction template range obtained during construction. The method further includes: when the remaining shot pair value of a geophone within the acquisition construction template is 0, moving the geophone within the template to the preset position of the geophone in the next round of the construction scheme, and calculating the remaining shot pairs of the geophone.

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.

This application provides a method, apparatus, equipment, and medium for well logging curve standardization, relating to the field of petroleum exploration and development technology. The method includes: determining a set of marker layers for a target well and checkpoints corresponding to each marker layer in the set, with each marker layer having at least one checkpoint; obtaining a set of well logging curves for the target well; for each marker layer, based on a subset of well logging curves for that marker layer, determining the deviation index value of each checkpoint on various types of well logging curves within that subset; for each type of well logging curve, based on the deviation index value of the checkpoint on that type of well logging curve, determining the target comprehensive deviation index value corresponding to that type of well logging curve; and standardizing the well logging curves of the target well according to the target comprehensive deviation index values ​​corresponding to various types of well logging curves. This application effectively solves the problems of low accuracy and poor reliability in existing well logging curve standardization based on a single marker layer.

This invention relates to the field of petroleum exploration and development technology, and discloses a method and device for high-precision identification of low-order faults in tight sandstone channels. The invention first simulates the river channel based on geological analysis results of the study area, integrating the simulated channel into a horizontal reflectivity model. Then, based on this, fault and fold simulations are performed according to the geological analysis results. Finally, the reflectivity model is convolved with Ricker wavelets to generate a 3D seismic data volume through forward modeling. An improved Unet network model is constructed, and the network model is trained using the 3D seismic data volume obtained through forward modeling. After training, the 3D seismic data volume to be predicted is fed into the trained model to achieve automatic identification of low-order faults in tight sandstone channels. This invention, through deep learning algorithms, fully explores the potential features of seismic data, greatly improving the identification capability of low-order faults and effectively distinguishing lithological boundaries and fault boundaries, thus improving the accuracy of geological interpretation.

The application belongs to the technical field of oil exploration, and particularly relates to a river sandstone delineation method and device, an electronic device and a storage medium. The application obtains seismic data of a target area and logging data of at least two sample wells, the logging data corresponding to the sample wells, determines a dominant incidence angle range of a region where each sample well is located according to each logging data and the seismic data, determines a comprehensive response data body of the target area according to all the dominant incidence angle ranges and the seismic data, and determines a delineation result of river sandstone according to the comprehensive response data body. The final delineation result is more consistent with the actual drilling result.

This application provides a reservoir permeability prediction model generation and prediction method, apparatus, equipment, and medium, relating to the field of petroleum exploration technology. The model generation method includes: generating multiple target data; determining multiple reservoir permeability intervals and their corresponding target datasets based on the target data; constructing membership functions corresponding to the reservoir permeability intervals based on fuzzy logic and determining the parameter values ​​in the membership functions; determining the target sample set corresponding to each reservoir permeability interval according to the membership degree corresponding to each target data under different membership functions; dividing the target sample set corresponding to the reservoir permeability interval into a first sample set and a second sample set, and training the initial reservoir permeability prediction model separately to obtain two target reservoir permeability prediction models corresponding to the reservoir permeability interval. This application can effectively solve the problem of low prediction accuracy in predicting reservoir permeability based on the correlation between porosity and reservoir permeability.

This invention relates to a method, device, electronic equipment, and medium for scheduling fracturing equipment based on digital twins, belonging to the field of resource optimization technology in petroleum exploration operations. The method applies digital twin technology to the scheduling of fracturing equipment. By constructing a twin well site, selecting a scheduling scheme, and conducting simulations and iterations, a better scheduling scheme is obtained. Combined with manual intervention, historical database analysis, and access control, this improves the efficiency of fracturing equipment management, reducing idle time caused by relying on manual experience, minimizing blind spots in fracturing resource scheduling, lowering costs, and increasing operational efficiency. The device, electronic equipment, and medium based on this invention improve the application efficiency of the method and expand its applicability. It is suitable for scheduling fracturing equipment.

This invention relates to the field of petroleum exploration and development, specifically to a multi-scale fracture and fracture-cavity prediction method, medium, and equipment. The method includes: acquiring raw seismic data of the area to be predicted; performing interpretative enhancement processing on the raw seismic data to construct a multi-attribute discontinuity model for fracture identification with attitude constraints; based on step S3, integrating regional tectonic evolution and fracture formation mechanisms, analyzing the spatial distribution characteristics of fractures in the target area, and evaluating the potential for formation of fault-controlled fracture-cavity dominant reservoirs; further predicting the oil and gas accumulation potential within potential dominant reservoirs based on the evaluation of fault-controlled fracture-cavity; and performing three-dimensional geological visualization of the results. This invention addresses low signal-to-noise ratio seismic data by establishing a combined enhancement processing technology workflow, effectively removing random noise, enhancing seismic reflections at fracture sites, broadening the seismic frequency band, and restoring low-frequency and high-frequency energy, resulting in high signal-to-noise ratio, high resolution, and clearly defined fault points.

This utility model relates to the field of petroleum exploration and extraction technology, and discloses a mobile laboratory for on-site real-time testing of shale oil. It includes a driver's cab, a cargo box located on one side of the driver's cab, a door on the outer wall of the cargo box, a filter assembly on the inner wall of the cargo box, and an expansion assembly on the inner wall of the cargo box. Both the driver's cab and the lower surface of the cargo box are equipped with casters. The expansion assembly includes an expansion box, the outer wall of which is slidably connected to the inner wall of the cargo box. In this utility model, the mobile laboratory travels to the testing site using the casters, opens the door to enter the cargo box, and uses a hydraulic rod in the expansion assembly to push the expansion box outward along a slide rail, unfolding the support structure to expand the experimental space. This achieves flexible expansion of the cargo box space, creating a more spacious and ample operating space for testing personnel, accommodating more advanced testing equipment, improving the convenience and efficiency of on-site testing work, and ensuring the smooth conduct of testing work.

The application discloses a kind of well fusion stratum water resistivity heterogeneity quantitative evaluation method, it is related to petroleum exploration and development technical field.The implementation process is as follows: obtain the stratum signal data of various well logging acquisition to calculate reference stratum water resistivity;Based on the feature data extracted in conventional well logging, a machine learning model is constructed, and the stratum water resistivity is the target variable of the machine learning model.The stratum water resistivity prediction model is obtained by training the machine learning model;Collect conventional well logging data, extract the feature data in conventional well logging data, input the stratum water resistivity prediction model, and output the stratum resistivity prediction value;Stratum resistivity prediction value at multiple depths forms a continuous prediction curve as the stratum water resistivity heterogeneity quantitative evaluation result, solves the accurate evaluation question under the lack of nuclear magnetic resonance logging data.

The application belongs to the technical field of oil exploration, and discloses a multi-dimensional intelligent crude oil property rapid identification method and device, wherein the multi-dimensional intelligent crude oil property rapid identification method comprises the following steps: S1. obtaining well data analysis of crude oil density; S2. determining the law between the gas logging parameter and the crude oil density; S3. screening the gas logging parameter; S4. performing operation by using formula 1 to obtain the crude oil property; and the multi-dimensional intelligent crude oil property rapid identification device comprises a data collection module, a data preprocessing module, a feature extraction module, a model training module, a crude oil property identification module and a result output module. The application is convenient for rapidly identifying the crude oil property under different crude oil property conditions.

The embodiment of the present application provides a kind of shear wave time difference prediction method and device, belong to petroleum exploration development technical field.The method comprises: obtaining well logging sample data as the training data set of prediction model;The training data set is preprocessed, data screening is carried out based on importance analysis, data grouping is carried out based on kurtosis and skewness, and the processed training data set is obtained;The processed training data set is input into the neural network of CNN and LSTM hybrid building respectively for training, and the shear wave time difference prediction model is obtained;Obtain the well logging data of the shear wave time difference to be predicted;The well logging data is preprocessed, well logging data grouping is carried out based on kurtosis and skewness, and the processed well logging data is obtained;The processed well logging data is respectively input into the shear wave time difference prediction model, and the shear wave time difference is obtained.The shear wave time difference prediction method and device of the present application have the advantages of high processing efficiency, high prediction accuracy and strong regional applicability.

The present application belongs to the technical field of oil exploration, and relates to a method for identifying late-stage natural gas charging proportion. The method comprises the following steps: calculating a crude oil conversion rate; calculating a calculated value of a gas-oil ratio of a reservoir; establishing a corresponding relationship between the sum of the absolute concentrations of 3-methyl durene and 4-methyl durene and a measured value of the gas-oil ratio of the reservoir; taking the sum of the angle concentrations as a benchmark, adjusting the calculated value of the gas-oil ratio of the reservoir, so that the late-stage natural gas proportion is 0-99%, and obtaining a late-stage natural gas charging proportion identification chart; detecting the sum of the absolute concentrations of 3-methyl durene and 4-methyl durene in the crude oil to be evaluated; and based on the sum of the absolute concentrations and the measured value of the gas-oil ratio of the reservoir, according to the late-stage natural gas charging proportion identification chart, the identification of the late-stage natural gas charging proportion in the oil and gas reservoir to be evaluated is realized. The method is fast, intuitive and easy to operate, and improves the speed and accuracy of the identification of the late-stage natural gas charging proportion.

This invention relates to the field of petroleum exploration technology, specifically to a soil layer surveying device for petroleum drilling engineering surveying. It includes a main frame and further comprises: a hydraulic telescopic rod, symmetrically and vertically fixed to the main frame; a lifting drive frame, fixed to the top of the telescopic end of the hydraulic telescopic rod; a penetration clamping cylinder, located in the middle of the lifting drive frame, with open upper and lower ends for clamping and allowing the probe rod to pass through; and an auxiliary loading and unloading mechanism located above the penetration clamping cylinder. The auxiliary loading and unloading mechanism includes a loading and unloading sleeve coaxially arranged with the penetration clamping cylinder; a rotating drive ring is coaxially rotatably connected inside the loading and unloading sleeve. This invention integrates the functions of automatic probe rod supply, threaded connection, uniform speed penetration, segmented extraction, and automatic retrieval and storage, forming a complete closed-loop operation process. This reduces the frequent manual handling, alignment, and tightening of heavy physical labor and work interruptions in traditional exploration, significantly improving daily work efficiency.

The application provides a horizontal well coiled tubing extension tool and method, and belongs to the technical field of oil exploration and development equipment. The tool comprises at least two telescopic stepping mechanisms connected in series, each mechanism comprising a shell, a throttling sleeve, a piston assembly, a guide support mechanism and a reset mechanism. A pressure difference is generated in the throttling sleeve by liquid, which drives the axial movement of the piston assembly, and drives the radial extension of the support cylinder slider to support the well wall; when the pressure difference disappears, the reset spring pushes the shell to reset, and the support cylinder slider is retracted, realizing step-by-step advancement. Adjacent mechanisms are connected through a central flow channel, and can be continuously and cyclically extended. The tool does not require an electric control system, has a simple and reliable structure, can adapt to different well diameters, has high energy utilization efficiency, can effectively reduce friction and improve the running efficiency and operation depth of the coiled tubing in the horizontal well.

The embodiment of the invention provides a method and a system for evaluating oil and gas storage conditions at the periphery of a back-flushing crawler, and belongs to the technical field of oil exploration. The method comprises the following steps: acquiring basic data of a target area, and identifying geological features based on the basic data; logging data of a target area are collected, and oil and gas storage state recognition is executed based on the logging data; key evaluation index identification is carried out based on the geological features and the oil and gas storage state; and based on the logging data of the target area, assigning each key evaluation index, and based on the assigned key evaluation index, evaluating the oil and gas storage condition. According to the scheme, the relevance and sensitivity of the multi-dimensional data are comprehensively considered, the favorable area, the general area and the unfavorable area can be effectively divided and stored in the complex geological area, and the method has important guiding significance for actual oil-gas exploration and development.

The application discloses a method and system for determining a lower limit value of a salt rock deposition thickness of rehydrocarbon generation of a hydrocarbon source rock, and relates to the technical field of oil exploration.The method comprises the following steps: calculating a top surface temperature T1 of the hydrocarbon source rock before salt rock deposition based on a deposition thickness Z1 of a stratum above the hydrocarbon source rock before the salt rock deposition; calculating a top surface temperature T2 of the hydrocarbon source rock after the salt rock deposition based on the deposition thickness Z1 of the stratum above the hydrocarbon source rock before the salt rock deposition and a salt rock deposition thickness Z2; when T2 >= T1, the hydrocarbon source rock will generate hydrocarbon again based on the top surface temperature T1 of the hydrocarbon source rock before the salt rock deposition and the top surface temperature T2 of the hydrocarbon source rock after the salt rock deposition; and calculating the lower limit value Z3 of the salt rock deposition thickness when T2 = T1 > a hydrocarbon generation threshold temperature.The application can quantitatively characterize the thermal state of the hydrocarbon source rock under the salt rock by clearly studying the salt rock thickness, the thermal physical property parameters of the salt rock and the surface heat flow, and can clearly determine the maturity of the hydrocarbon source rock, thereby providing a basic basis for further studying the evolution of the hydrocarbon source rock under the salt rock and the oil and gas reservoir forming process.

This invention relates to a downhole pulse generator and its control method and system, belonging to the technical field of petroleum exploration and drilling. The invention comprises a downhole pulse generator plunger pump, a pulse valve, and a control valve. The pulse valve is located at one end of the plunger pump and connected to it. The control valve is located at the end of the plunger pump away from the pulse valve and connected to it. The control valve drives the plunger pump to generate hydraulic pressure, causing the pulse valve to generate pulses under the action of the hydraulic pressure. The plunger pump includes a movable hydraulic piston and an adjustment assembly for driving the hydraulic piston. The adjustment assembly is configured to adjust the stroke of the hydraulic piston to regulate the hydraulic pressure and the pulse magnitude. The technical solution disclosed in this invention solves the problem that existing downhole pulse generators transmit signals solely through the presence or absence of pulses, using intermittent time to represent zeros in the encoding, which easily leads to information confusion and disorder, resulting in unreliable signal transmission.

This invention discloses a method for evaluating oil saturation based on the self-sealing capacity of tight reservoirs, relating to the field of petroleum exploration and development technology. First, this invention fits an acoustic transit time-depth trend line based on conventional logging data, and uses the Eaton method to calculate the total overpressure and separate hydrocarbon generation pressurization. Second, through high-pressure mercury injection experiments and conversion of charging characteristics, the relationship between pore throat radius and oil saturation is determined. Then, based on the capillary pressure formula and hydrocarbon generation pressurization intensity, the critical charging pore throat radius is determined. Based on mechanical equilibrium relationships, the upper limit of the self-sealing pore throat radius is determined. Finally, the effective reservoir pore throat range is defined, and oil saturation is calculated. This method overcomes the technical shortcomings of traditional methods that neglect the dynamic coupling relationship between hydrocarbon generation pressurization, pore throat charging, and self-sealing capacity during tight oil accumulation, resulting in large evaluation errors.

The invention relates to a flexible logging instrument and a manufacturing method of a flexible pipe of the flexible logging instrument, and relates to the technical field of oil exploration. The flexible logging instrument comprises a flexible pipe, the flexible pipe is made of metal, the flexible pipe comprises an inner pipe and an outer pipe arranged outside the inner pipe in a sleeving mode, the inner pipe comprises straight pipe sections and corrugated pipe sections, the straight pipe sections and the corrugated pipe sections are alternately arranged, a plurality of kerfs are formed in the outer pipe, and the outer pipe is divided into a plurality of independent pipe joints through the kerfs. The inner pipe in the flexible pipe comprises the corrugated pipe section, so that the inner pipe has certain telescopic capacity and bending capacity, and the straight pipe section in the inner pipe ensures certain structural strength while having the telescopic capacity and the bending capacity. The outer pipe arranged outside the inner pipe in a sleeving mode forms a plurality of independent pipe joints through a plurality of formed kerfs, the kerfs enable the pipe joints to move relative to one another, the outer pipe also has certain telescopic capacity and bending capacity, and the logging instrument can be bent, stretched and retracted to a certain degree in the underground logging process.

This invention belongs to the field of petroleum exploration and development technology, and relates to a method, electronic device, and computer-readable storage medium for determining fracture porosity. The method includes the following steps: Step S1: Calculating fracture porosity using imaging logging data; Step S2: Calculating fracture porosity using different dual-lateral models; Step S3: Comparing the fracture porosity from Step S1 with that from Step S2, and selecting the dual-lateral model with the smallest difference; Step S4: Inverting the coefficients of the dual-lateral model with the smallest difference from Step S3 by block, and determining the empirical parameter formula for fracture porosity. This invention applies imaging logging data, selects a suitable calculation model, and inverts the model's calculated coefficients to establish a suitable fracture porosity evaluation model, solving the problem of calculating fracture porosity using dual-lateral logging.

This application discloses a method, apparatus, electronic device, and storage medium for processing petroleum exploration data. The method includes: establishing a connection with a target server; sending a target petroleum exploration file request to the target server; receiving the target petroleum exploration file sent by the target server; parsing the target petroleum exploration file; acquiring target petroleum exploration data for a target time period; and displaying a target trend graph formed by the target petroleum exploration data for the target time period on a display interface. This solves the problems of monotonous display interfaces, poor interactivity, and difficult troubleshooting in existing technologies, achieving data visualization, improving resource utilization, shortening response time, reducing the complexity of using multiple management tools, and improving operational efficiency.

This invention relates to a method for detecting the oil-bearing potential of thin clastic reservoirs, belonging to the field of petroleum exploration and development technology. The invention first performs fine calibration of the target layer using synthetic records, extracting its wave impedance properties. Then, it uses drilled well data and 3D seismic data covering the reservoir distribution area of ​​the target region to extract the integrated energy properties of that frequency band, and extracts the formation attenuation slope properties. Next, it performs cross-plot analysis on the obtained wave impedance properties, frequency band integrated energy properties, and formation attenuation slope properties to determine the oil-bearing range of the thin clastic reservoir. This invention comprehensively considers the influence of wave impedance properties, frequency band integrated energy properties, and formation attenuation slope properties on the oil-bearing potential of thin clastic reservoirs, improving the detection accuracy of oil-bearing potential in thin clastic reservoirs. The detection results show a high degree of agreement with actual drilled wells, laying the foundation for efficient exploration and development of thin clastic reservoir oil reservoirs.

This invention relates to a comprehensive grading and evaluation method for deltaic sand-rich lithological traps, belonging to the field of petroleum exploration and development technology. The invention discloses a comprehensive grading and evaluation method for deltaic sand-rich lithological traps, including obtaining the geological background, core data, development data, well logging data, and seismic data of the target area; establishing a high-frequency sequence stratigraphic framework; characterizing sedimentary microfacies; predicting the thickness distribution of sand bodies and mudstones; determining the evaluation value of the lateral boundary of the lithological trap; determining the evaluation value of the caprock conditions of the lithological trap; determining the comprehensive trap score based on the evaluation values ​​of the lateral boundary and caprock conditions of the lithological trap, and performing a grading evaluation. This invention mainly establishes a high-frequency sequence stratigraphic framework, utilizes various geophysical techniques, establishes relevant evaluation processes and standards, and grades the lateral conditions and caprock conditions of lithological targets from geological, geophysical, and quantitative mudstone thickness perspectives, performing a semi-quantitative evaluation.

This invention relates to a well logging tool balance piston positioning device and its usage method, belonging to the field of petroleum exploration technology. The well logging tool balance piston positioning device of this invention includes a positioning gauge and a positioning ring. The positioning ring is sleeved on the outer wall of the balance piston and located inside the well logging tool. The positioning gauge includes a frame and a magnetic ball. The magnetic ball and the positioning ring are mutually attracted, and the magnetic ball can roll freely inside the frame. The surface of the frame is provided with graduations, and the outer wall of the well logging tool is provided with a reference line for positioning one end of the frame. By sleeved on the piston with the positioning ring that is mutually attracted to the magnetic ball, the magnetic ball, which can roll freely inside the frame, can stop at the position of the positioning ring. Using the graduations on the frame and the reference line on the outer wall of the well logging tool, the position of the balance piston in the well logging tool can be indirectly determined to determine the amount of oil in the well logging tool. The method of use is simple, the detection results are intuitive, and it does not damage the well logging tool itself.

This invention provides a phase-controlled inversion method based on a fracture-vuggy structure model of ultra-deep carbonate rocks, belonging to the field of petroleum exploration and development technology. The phase-controlled inversion method includes steps S1-S6. The phase-controlled inversion method provided by this invention utilizes seismic sensitivity attribute analysis, combined with geological understanding of deep strata, to calibrate the fracture-vuggy structural elements of ultra-deep reservoirs, and establishes an ultra-deep phase-controlled low-frequency model. This improves the accuracy of prediction for complex carbonate reservoirs with strong heterogeneity and rapid lateral variations. Through phase-controlled impedance inversion, under prior constraints, it reduces the ambiguity of reservoir internal identification, improves the accuracy of ultra-deep reservoir prediction, and increases the resolution of ultra-deep carbonate fracture-vuggy reservoir identification, providing a new technical means for the exploration and development of carbonate fracture-vuggy reservoirs.

The application relates to the technical field of oil exploration, and provides a method and device for determining effective porosity of a shale oil reservoir. The method comprises the following steps: obtaining target well logging data to obtain formation density and total organic carbon content of a target formation; determining whether the target well logging data comprises element full spectrum logging data; if yes, performing normalization analysis on the element full spectrum logging data, and if not, performing combined analysis on preset well logging data in the target well logging data to obtain inorganic framework mineral component content information and clay content of the target formation; calculating mixed inorganic mineral framework density according to the inorganic framework mineral component content information; and calculating effective porosity of the target formation by using the formation density, the total organic carbon content of the dry kerogen, the mixed inorganic mineral framework density and the clay content. According to the embodiment of the application, the influence of organic and inorganic mineral frameworks on porosity can be considered, so that the calculation precision of the effective porosity of the shale oil reservoir is improved.

The application belongs to the technical field of oil exploration, and discloses a method, device, equipment and medium for reconstructing pseudo-acoustic wave curves based on deep learning, which comprises the following steps: collecting logging lithology and response data, and establishing deep learning training samples; after standardizing the deep learning training sample set, dividing the sample set into a training set and a verification set according to a proportion; establishing a deep learning model; setting model training parameters; training and verifying the data set in the training sample set until the training is stopped after the requirements are met, and saving the trained deep learning model; applying the trained deep learning model to each well in the work area in sequence to obtain the reconstructed target curve. The reconstructed pseudo-acoustic wave curve has multi-lithology identification capability, reduces the dependence on the professional technical background of the user, and has a significant improvement in the efficiency, accuracy and user friendliness of the pseudo-acoustic wave curve reconstruction, and is suitable for identifying multi-lithology reservoirs with complex lithology.