31 results about "Clastic rock" patented technology

The invention belongs to the technical field of oilfield development, and discloses an oil and gas reservoir modeling processing system based on clastic rocks and a use method of the oil and gas reservoir modeling processing system. The data processing system is used for processing fault and logging data, geological stratification data and well perforation data, the grid management system is used for dividing and encrypting grid types, the model building system is used for building a digital-analog model and an oil-gas reservoir relation model, and the digital-analog management system is used for outputting the built model. And the established digital model is convenient to modify and reconstruct, so that the digital model pretreatment work requirement of complex oil and gas reservoir types is met, the historical fitting speed of subsequently realizing numerical simulation is improved, and the modeling treatment of clastic rock oil and gas reservoirs is facilitated.

The invention discloses a clastic rock sedimentary bedding type rapid identification method and system, and the method comprises the steps: carrying out the high-resolution scanning of a rock core column image through scanning equipment, obtaining a collection image, sequentially carrying out the image preprocessing and meshing of the collection image, and obtaining a sample image; carrying out edge detection on the sample image to obtain a sample texture layer line, and carrying out skeletonization processing on the sample texture layer line to obtain a sample texture layer curve set; according to the method, the functions of extracting the morphological parameters of the sample sedimentary stratification of the high-resolution rock core scanning image by adopting an image processing technology and quantifying the similarity between the sample sedimentary stratification and the standard sedimentary stratification by utilizing a mathematical algorithm to accurately recognize the type of the sedimentary stratification are realized, so that the recognition efficiency of the sedimentary stratification of the clastic rock is improved; and the identification accuracy of the clastic rock sedimentary stratification is guaranteed, the working efficiency of field investigation and indoor rock core description of geological workers is improved, and the method is suitable for being widely popularized and used.

The invention discloses a logging curve adaptive clustering ultrafine lithology classification method for enhancing carbonate rock-clastic rock transition type lithology identification, and relates to the technical field of lithology classification. The method comprises the steps that after logging data are loaded, missing values are processed firstly, and samples with the non-null-value proportion larger than or equal to 80% are reserved; preprocessing the well logging data after completion; screening the geologic features, and removing geologic redundant information; the global structure and local lithology details of the sedimentary system are reserved through UMAP self-adaptive dimensionality reduction; hDBSCAN clustering parameters are determined in a self-adaptive mode based on the sedimentary body scale and the lithologic continuity, and quantitative evaluation and early warning are carried out on the clustering quality; and finally, based on traditional color matching of sedimentary geology, lithology-color geological mapping is established, and lithology distribution of sequence cycle is visually reflected. The method can meet the high-precision lithology classification requirements of complex stratums (such as heterogeneity, curve missing and multiple transition type lithology).

The present application relates to a kind of methods for restoring porosity evolution of clastic reservoirs under tectonic extrusion, belonging to the technical field of oil and gas exploration and development.The method comprises the following steps: calculating the total compaction and pore loss of clastic rock samples, selecting samples with similar burial depth, similar rock structure and different maximum paleo-tectonic stress as selected samples, obtaining the lateral compaction and pore loss of the one with larger maximum paleo-tectonic stress by the difference of total compaction and pore loss corresponding to the two selected samples adjacent to the maximum paleo-tectonic stress, and establishing the functional relationship between lateral compaction and pore loss and maximum paleo-tectonic stress;calculating the lateral compaction and pore loss of each lateral extrusion in multiple lateral extrusions;calculating the vertical compaction and pore loss according to the total compaction and pore loss and lateral compaction and pore loss, and establishing the relationship chart between vertical compaction and pore loss and burial depth;using the inverse back stripping method, combining lateral compaction and pore loss and vertical compaction and pore loss, and drawing the porosity evolution curve of clastic reservoirs in geological history under tectonic extrusion.This method solves the problem of being unable to quantitatively calculate lateral and vertical compaction and pore loss in the process of restoring porosity evolution of foreland basin reservoirs.

The invention relates to a method for identifying a clastic rock low-resistivity oil layer in a salt lake sedimentary environment, and belongs to the technical field of oil exploration and development. The identification method for the clastic rock low-resistivity oil layer in the salt lake sedimentary environment comprises the following steps: determining an identification standard of a dry layer and a production layer in a target layer of a research area based on a corresponding relation of porosity data, permeability data and reservoir types of the target layer encountered by a standard well in the low-resistivity research area; based on the corresponding relation of the irreducible water saturation, the movable water saturation and the reservoir type of the standard well drilling encountering target layer in the research area, the identification standards of the oil layer, the same oil-water layer and the water layer in the production layer in the target layer in the research area are determined. According to the method for identifying the clastic rock low-resistivity oil reservoir in the salt lake sedimentary environment, the reservoir seepage characteristics are considered, the Archie formula is corrected, and the movable water saturation is introduced, so that the identification accuracy of the low-resistivity oil reservoir can be effectively improved.

The invention belongs to the technical field of oil and gas seismic exploration interpretation, and discloses a method for improving prediction precision of a clastic rock thin reservoir, application, a device and a medium. The method comprises the steps that a thin sand body plane distribution outline is recognized through seismic waveform decomposition, and then a thin sand body boundary is recognized through seismic waveform indication simulation; and finally, details of the thin sand body are depicted through inversion of post-stack geostatistics, namely, prediction of the clastic rock thin reservoir is completed, and through series connection of three post-stack reservoir prediction methods according to a specific sequence, combined application after improvement and progressive layer by layer, description of details from planar distribution of the contour of the thin sand body to the boundary of the thin sand body to the interior of the thin sand body is achieved step by step. The device and the computer readable storage medium according to the method can be used for improving the prediction precision of the thin reservoir of the clastic rock, and the method is suitable for depicting lithologic traps and oil and gas reservoirs of the stratum of the thin reservoir of the clastic rock.

The present application provides a drilling temperature and hydrocarbon accumulation period prediction method and a drilling temperature prediction device, and solves the problem of temperature prediction deviation in actual exploration and production. The drilling temperature prediction method comprises: judging whether the shallow clastic rock layer system of the study area has drilling data; if yes, obtaining the rock thermal conductivity data of the clastic rock based on the drilling data; if no, obtaining the rock thermal conductivity data under different porosity conditions after the change with the burial depth based on the rock thermal conductivity data measured by the outcrop of the study area; collecting the field or drilling samples corresponding to the formation of the study area, and determining the rock thermal conductivity data of the deep carbonate rock formation for the field or drilling samples; establishing a rock thermal conductivity model of the study area based on the rock thermal conductivity of the clastic rock, the rock thermal conductivity data under different porosity conditions after the change with the burial depth, and the rock thermal conductivity data of the deep carbonate rock formation; and obtaining the formation temperature of the drilling based on the rock thermal conductivity model of the study area to predict the drilling temperature.

The invention belongs to the technical field of geophysical exploration, and discloses a method and a device for drawing a clastic rock sedimentary facies diagram by using a digital language and a medium, lithology data is processed and then combined with seismic attributes, and the clastic rock sedimentary facies diagram is simply and quickly drawn through digital processing. According to the method, uncontrollable interference of human factors in a traditional method is overcome, and errors and low efficiency caused by human cognitive differences and experience differences are avoided. The method is simple and convenient in process and high in accuracy, the device and the medium based on the method are convenient to use, the clastic rock sedimentary facies diagram can be rapidly and efficiently drawn, the facies belt analysis efficiency is greatly improved, and great contribution is made to oil and gas exploration and development projects.

The invention belongs to the technical field of reservoir geological modeling, and provides a clastic rock oil and gas reservoir key interface characterization modeling method, device, equipment and medium, and the method comprises the steps: constructing a geological modeling basic database; key interface identification and representation are carried out based on the constructed geological modeling basic database; constructing a construction model based on the recognition and representation results of the key interface, the seismic data volume and the well data; checking whether a geological interface in the tectonic model is consistent with well data and seismic interpretation, and if not, optimizing the tectonic model; based on the sedimentary microfacies data, a deterministic assignment method is adopted to construct a sedimentary microfacies model; based on the sedimentary microfacies model, a sequential indication method is adopted for simulation, and a lithologic model is constructed; constructing an attribute model based on the lithologic model; according to the method, the structure model is optimized, so that the structure model restores the structure characteristics as much as possible, and reliable spatial constraints are provided for coarsening and modeling of attributes such as lithology, porosity, permeability and saturation.

This utility model discloses a clastic rock sediment monitoring device, including an L-shaped mounting plate. A fixed plate and a microcontroller are mounted on top of the L-shaped mounting plate. A slider is vertically mounted on the fixed plate, and a signal receiver is mounted on the slider. An infrared signal output receiver is mounted on the top of the fixed plate. It also includes an infrared signal transmitter, which is adhered to the clastic rock. The microcontroller is electrically connected to the signal receiver, the infrared signal transmitter, and the infrared signal output receiver. A groove is provided on the fixed plate, and a threaded rod is provided inside the groove. Both the threaded rod and the groove are arranged along the height direction of the fixed plate, and the upper end of the threaded rod protrudes from the fixed plate and is connected to the output shaft of a rotating motor. This utility model, by including an infrared signal transmitter, a signal receiver, and an infrared signal output receiver, can conveniently monitor sedimentation.

The invention relates to the technical field of oil and gas field development, and discloses a clastic rock gas reservoir water invasion dominant channel prediction method, which comprises the following steps: S1, data acquisition and preprocessing: collecting static geological data and dynamic production data related to a clastic rock gas reservoir, and carrying out standard unification, noise processing and standardization on the data to obtain a data base; establishing a working model and forming a comprehensive input data set; s2, reservoir feature construction based on an input data set; s3, carrying out connectivity modeling; s4, water invasion risk analysis; s5, identifying a water invasion dominant channel; and S6, dynamically updating. A comprehensive prediction framework of connectivity modeling and water invasion risk analysis is established on the basis of constructing and fusing static geological data and dynamic production data, and cooperative calculation of a reservoir space structure, seepage characteristics and dynamic response is carried out, so that identification and trend prediction of a water invasion dominant channel in a clastic rock gas reservoir are realized. And the timeliness and accuracy of reservoir water invasion evolution analysis are improved.

This invention belongs to the field of oil and gas field reservoir engineering technology, specifically a method for characterizing the impact of clastic reservoir heterogeneity on reservoir efficiency. First, mineral composition, porosity and permeability, mechanical parameters, and spatial configuration of the study area are obtained. Based on the interlayer spatial configuration, flow units are divided to quantitatively evaluate the constraints of interlayers on effective reservoir space. Through creep experiments and alternating load experiments, mechanical property degradation models of different types of interlayers under long-term high pressure and injection-production cycles are established. A dynamic model of interlayer sealing capacity evolution is constructed to quantify its long-term potential to suppress vertical fluid flow. By coupling the interlayer volumetric sweep efficiency, the mechanical degradation model, and the sealing capacity evolution model, a comprehensive reservoir efficiency impact coefficient is established, enabling a quantitative evaluation of reservoir efficiency under different types of interlayer constraints. This invention elevates the impact of interlayer heterogeneity on reservoirs from a static description to a dynamic quantitative evaluation, providing a scientific basis for the site selection optimization and injection-production strategy formulation of underground reservoirs.

This invention establishes a method and system for three-dimensional facies-controlled sand body modeling and connectivity evaluation. The method is based on a dimensionality-reduction modeling architecture: a planar sedimentary facies distribution map is generated through probability-guided sequential indicator simulation; under the constraint of planar facies zones, a one-dimensional vertical sequence of interbedded sand and mud layers is independently generated point-by-point using probabilistic sampling; the planar facies map and the vertical sequence are stitched together in three-dimensional space; then, based on graph theory undirected graph algorithms, the connectivity of the three-dimensional sand body is identified using vertical depth interval overlap and non-interlayer occlusion as dual criteria; finally, connectivity uncertainty is quantified through Monte Carlo iteration. Compared with traditional full-3D grid sequential Gaussian simulation, this method is applicable to clastic reservoirs with gradual lateral variation and dominant vertical accretion (lateral variation coefficient of planar facies zones less than 0.3). It eliminates the computationally expensive three-dimensional spatial interpolation and complex structural modeling, forming a simplified engineering path of "trading computational power for uncertainty assessment," which can be used for reservoir connectivity evaluation and development scheme optimization.

The invention discloses a method and a system for calculating rock electrical parameters of a clastic rock reservoir. The method comprises the following steps: calculating clay contents and corresponding shale contents under different depths in the clastic rock reservoir to be evaluated; according to the clay content, various factors influencing rock electrical parameters are analyzed, so that apparent rock electrical parameter values at different depths are obtained; by analyzing the relationship between the shale content and the apparent rock electrical parameter value at different depths, a rock electrical parameter change curve changing along with the shale content is obtained, and a rock electrical parameter calculation result is obtained by using the curve. According to the method, after the influence of various factors on the rock electrical parameters is fully considered, the rock electrical parameter change curve for calculating the rock electrical parameters is obtained, so that the calculation method does not depend on experimental test data, and good calculation precision is kept while the calculation process is simplified. The method has very high universality for calculation of the rock electricity parameters of the clastic rock reservoir, and the purpose of rapidly and relatively accurately evaluating the logging can be achieved.

The application provides a clastic rock reservoir porosity evaluation method and application. First, well logging data is standardized, and the standardized well logging data is used for core homing treatment on core porosity obtained through experimental testing, so that corrected core porosity is obtained. A plurality of models for predicting porosity through three-pore well logging curves are established by using the above data, and accurate prediction of porosity is realized. The model is based on geophysical and mathematical thinking, and combines the influence of reservoir variable skeleton, so that the accuracy of porosity well logging interpretation is greatly improved, the cost of well logging interpretation is reduced, and application in the fields of oil and gas exploration and development and geophysical well logging is realized.

This utility model discloses a comparison device for describing clastic rock cores, including a comparison shell, an adjusting rod, a magnifying glass, and a supplementary light. A vertical plate and two placement platforms are fixedly mounted on the upper surface of the comparison shell, with the two placement platforms positioned on the same side of the vertical plate. A tablet computer is mounted on the side area of ​​each placement platform corresponding to the vertical plate. A magnifying glass and a supplementary light are adjustablely mounted above each placement platform via the adjusting rod. A control panel is also provided on the vertical plate. This utility model, through the comparison shell and the cooperation of the comparison shell and placement platforms, allows for the placement and observation of clastic rock cores requiring comparison. The magnifying glass and supplementary light facilitate observation and processing of the clastic rock cores by staff. The adjusting rod allows for easy adjustment of the positions of the magnifying glass and supplementary light, enabling observers to conduct detailed observation of the clastic rock cores.

The invention discloses a clastic rock sedimentary landform recovery method and device, a medium and computing equipment. The method comprises the following steps: establishing a clastic rock sedimentary landform interpretation research work area; acquiring a seismic stratigraphic interface of the target recovery interface; obtaining an interface seismic layering of an overlying stratum of the target stratum; obtaining a minimum isochronous seismic stratum interface of an overlying stratum of the target stratum; performing analysis based on the seismic event contact relationship, and obtaining the number of upper exceeding points of the target recovery interface; obtaining the micro-drift amount of the micro-drift surface; acquiring a spatial azimuth angle and a point inclination angle of discrete data points in a three-dimensional seismic target range; obtaining a point inclination angle and an azimuth angle of the target recovery interface and the micro floating surface; calculating the impression thickness of the target recovery interface; and recovering the sedimentary landform of the clastic rock. According to the method, the impression thickness of the target recovery interface can be calculated more accurately, then the clastic rock sedimentary landform is recovered, a scientific foundation is laid for well position deployment and the like, and the economic benefits of oil field exploration and development are improved.

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.

The invention discloses an iodoform-epoxy resin embedding preparation method for SEM-EDS analysis of a coalbed methane reservoir sample, and relates to the technical field of reservoir sample detection. The method comprises the following steps: cutting, cleaning and performing low-temperature vacuum drying on a coalbed methane reservoir sample; adding iodoform into the epoxy resin, and fully stirring until the iodoform is completely dissolved to form a uniform and clear mixed solution; then adding a curing agent and stirring at a low speed; after natural and vacuum combined defoaming, embedding and curing the sample; and finally, a flat observation surface is obtained through step-by-step mechanical polishing and argon ion polishing, and sample preparation is completed after conductive treatment. According to the method, iodoform is dissolved firstly, and then the curing agent is added, so that iodoform crystal agglomeration and bubble introduction are effectively avoided, the contrast of the backscattered electron image is remarkably improved, the primary pores and cleat structures of the coal rock are protected, and the EDS quantitative analysis precision is improved; the method is simple in process, controllable in process parameter, good in repeatability, suitable for various samples such as coal rock, coal-containing clastic rock and coal seam dirt band, and capable of providing high-quality sample preparation guarantee for coal bed gas reservoir microcosmic characterization.

The invention discloses a porosity prediction method and device for a clastic rock reservoir, equipment and a medium, and relates to the technical field of oil and gas reservoir prediction, data cleaning, abnormal value detection and processing and feature engineering processing are performed on logging effective sample data of the clastic rock reservoir, and a sample data set is obtained; constructing a porosity prediction model based on a deep learning algorithm and an integrated learning algorithm; dividing the sample data set by using a weighted integrated multi-algorithm framework, and performing data preprocessing on the divided data set to obtain a target data set; performing model training on the porosity prediction model based on a programming language framework, and performing model testing and performance evaluation on the trained porosity prediction model; taking the porosity prediction model passing the performance evaluation as a target porosity prediction model; and inputting the target well section data into the target porosity prediction model, and outputting a porosity prediction value, thereby improving the precision and stability of porosity prediction, and solving the problem that a complex nonlinear relationship cannot be effectively processed.

The invention provides an underground gypsum-salt rock stratum identification method and system, electronic equipment and a storage medium, and the method comprises the steps: obtaining the magnetotelluric frequency data of an underground rock stratum, and generating a magnetotelluric frequency CYT curve; obtaining a first difference parameter CG1 according to a difference value between a maximum extreme value envelope line LOGMAX and a minimum extreme value envelope line LOGMIN of the magnetotelluric frequency CYT curve; performing trend fitting based on a magnetotelluric frequency CYT curve to obtain a fitting straight line CNN; solving a difference value between the magnetotelluric frequency CYT curve and the fitting straight line CNN to obtain a second difference parameter CG2; and based on the obtained first difference parameter CG1 and the second difference parameter CG2, performing gypsum salt rock judgment and identification on the underground target stratum. According to the method, accurate recognition of the gypsum salt rock in the clastic rock stratum can be effectively achieved, the development condition of the gypsum salt rock in the non-drilling section can be predicted in drilling, and the method plays an important role in avoiding drilling accidents.

The invention provides a mapping method and system for basin clastic rock sedimentary facies, and the method comprises the steps: determining all sedimentary facies types possibly existing in a current basin through considering the terrain environment, stratum distribution and structural elements of a to-be-researched basin; aiming at different sedimentary facies types, respectively taking structures, material sources, landforms and sedimentary facies as research elements, and combining a set sedimentary facies control principle to analyze control association between each research element and the corresponding sedimentary facies; and respectively compiling sedimentary facies planar graphs of stratums in different periods of the current basin by adopting a point-line-plane mode based on the control correlation between each research element and the corresponding sedimentary facies. By adopting the scheme, the defects of complicated operation and insufficient map information accuracy in the prior art can be overcome, the control effect of factors such as the structure, the material source, the landform and the deposition on the sedimentary facies is comprehensively considered, and support is provided for the sedimentary facies evolution law and guidance of oil-gas exploration engineering.

This invention relates to the field of oil and gas field development and discloses a model construction method and system for multi-scale characterization of microfractures in compacted clastic rocks. The method includes: preparing artificial rock cores under simulated formation depth and pressure conditions within a reactor mold; simultaneously acquiring acoustic wave data axially passing through the artificial rock core during the compaction process; injecting epoxy resin adhesive into the artificial rock core after preparation; and slicing the artificial rock core to obtain corresponding cast thin sections after the adhesive has completely solidified; acquiring a full-view image of the cast thin sections and obtaining the number of fractures, fracture width, number of gravels, and surface fracture ratio from the full-view image; acquiring the number of acoustic pulse frames to obtain acoustic pulse frame images corresponding to different simulation depths; projecting the obtained surface fracture ratio onto the acoustic pulse frame image based on the same simulation depth conditions, and then correlating it with the full-view image of the cast thin sections to obtain a joint distribution model of image-surface fracture ratio-acoustic pulse frame number corresponding to the simulation depth, which is the final model.

This invention discloses a method and process for multi-stage borehole enlargement and shallow-depth coordinated anchoring of fractured rock and soil using a caisson-wall protection system. The anchoring method includes drilling anchor holes, constructing multi-stage borehole enlargement cavities, installing anchor cables, grouting, and anchoring. The multi-stage borehole enlargement cavities, from top to bottom, include at least one borehole body enlargement cavity and one borehole bottom enlargement cavity. After the anchor hole construction reaches the designed depth, drilling continues along the extension direction of the anchor hole, forming a bottom caisson connected to the bottom enlargement cavity to accommodate the debris and soil discharged during the multi-stage borehole enlargement construction. The bottom caisson has a columnar structure, and its diameter is smaller than the diameter of the bottom enlargement cavity. After the anchor hole construction is completed, multi-stage borehole enlargement is performed from top to bottom at different depths and shallow locations within the fractured rock and soil using a combination of casing and packers, forming boreholes of different levels at the bottom and body. This invention provides a technical solution for the active reinforcement of fractured rock and soil, effectively improving the stability of such structures.

The application discloses a curtain opening system dissolution quantitative evaluation method under a high-temperature closed background, which comprises the following steps: carrying out source partition on a research area, determining mineral composition, interstitial type and pore type of different source areas, and determining compaction intensity sequence of different source areas; reconstructing a time-space sequence of diagenetic fluid activity, establishing a dynamic model of fluid-rock interaction and pore evolution; determining a mineral differential dissolution conversion mechanism; quantifying mineral differential dissolution under a curtain opening / closed system; and based on mineral composition component difference, fluid type and mineral dissolution effect difference, establishing a curtain opening system deep clastic rock reservoir dissolution quantitative evaluation method under a closed background by combining diagenetic mineral quantitative statistics and theoretical calculation. The application realizes quantitative-semi-quantitative prediction of dissolution effect, thereby delimiting a favorable dissolution development area, and effectively improves reservoir prediction precision, provides a scientific basis for drilling deployment, and reduces exploration risk.

The application provides a method for resistivity correction of clastic rock reservoirs, and belongs to the technical field of oil and gas resource reservoir exploration; the method comprises the following steps: S1, standardizing the logging curve of the existing well of the reservoir to be analyzed to obtain a standardized logging curve; S2, based on the standardized logging curve and core data obtained in step S1, a multi-mineral model is used to solve the lithology profile of the reservoir to be analyzed, and the gravel content and the lime content of the reservoir to be analyzed are determined; S3, according to the gravel content and the lime content determined in step S2 and the resistivity to be corrected, the corrected resistivity is obtained according to a resistivity correction formula, and a correction chart is established. Compared with the prior art, the application realizes the resistivity correction of the clastic rock reservoirs containing gravel and lime, and improves the accuracy of the fluid logging interpretation of the complex clastic rock reservoirs.

The invention relates to the technical field of oil and gas resources, in particular to a seepage capacity analysis method and device for a deep clastic rock gas reservoir, and the method comprises the following steps: collecting logging, logging and seismic data of the deep clastic rock gas reservoir; complementing a missing well section by adopting a double-constraint method of geologic feature trend of the same layer of an adjacent well and seismic wave impedance and coherent body attribute inversion to form a standardized reservoir basic data set; and a functional plugging agent system is selected according to the temperature and pressure conditions of the reservoir, a temperature-pressure coupling curing test is carried out, bonding strength and microstructure detection is carried out, and the packing performance is verified. According to the method, the missing well section of the deep clastic rock gas reservoir is complemented by adopting a double-constraint method, so that the defect that the missing well section is complemented mostly by adopting single adjacent well geologic feature trend interpolation or single seismic attribute inversion in the traditional analysis of the seepage capacity of the deep clastic rock gas reservoir is overcome; therefore, the problem of large difference between the complemented reservoir data and the actual reservoir condition is solved.

The invention relates to a clastic rock sedimentary environment determination method and device, electronic equipment and a medium. The method comprises the steps that an original well logging curve aiming at a target block and well logging values corresponding to multiple sampling points on the original well logging curve are obtained; the natural gamma curve, the neutron curve, the density curve and the interval transit time curve are subjected to principal component and dimension reduction processing, a principal component curve is obtained, and sampling points on the principal component curve correspond to sampling points on the original logging curve; performing phase unit division on the target block according to the principal component value of each sampling point on the principal component curve to obtain a plurality of phase units; and for each phase unit, judging the deposition environment of the phase unit according to the natural gamma curve and the neutron curve corresponding to the phase unit. According to the method, the sedimentary environment of each facies unit is judged through the four logging curves of the natural gamma curve, the neutron curve, the density curve and the interval transit time curve of the target block, and the sedimentary environment of the stratum can be truly reflected.

The application discloses a kind of clastic rock fracture sweet spot identification method, device and equipment, the method comprises: based on the physical property parameters and geometric parameters of fracture, associated fracture zone and fracture zone in study area, construct the fracture system model of study area;With the fracture data obtained by seismic data interpretation in study area and / or part of fracture system model not constructed fracture data as constraint condition, the fracture system model is interpreted, to obtain the fracture system three-dimensional space data of study area;Based on the corresponding seismic attribute of stratum in study area, and the quantitative identification chart of pre-constructed rock physics-log data, determine the distribution area of clastic rock effective reservoir in study area;Based on fracture system three-dimensional space data and the distribution area of clastic rock effective reservoir, the development area of clastic rock fracture sweet spot is identified.The method greatly improves work efficiency and clastic rock fracture sweet spot identification precision, and has practical guiding significance for clastic rock fracture sweet spot exploration.

The application provides a method for dividing terrigenous clastic rock strata, which comprises the following steps: analyzing geological and logging data, and selecting logging curves Log which are sensitive to terrigenous clastic rock lithology and sedimentary cycle; using maximum overlap wavelet transform to decompose the logging curves into multiple frequency bands, and establishing a decomposition coefficient matrix based on depth domain and frequency band domain; starting from the depth domain, calculating maximum value and information entropy curves as a basis to divide the geological horizon of typical wells in the work area; taking the maximum value curve as a basis, and taking the adjacent typical well as a reference template, the geological horizon of other wells in the work area is divided by using the combination of the whole curve and the local curve comparison. The application combines the geological principle and the mathematical method, extracts more effective information which can reflect the lithology and the sedimentary cycle, reduces the requirement for the experience of personnel, and further improves the working efficiency of the stratum division by using the similarity of the logging curves in the same sedimentary environment.