89 results about "Clastic rock" patented technology

The invention provides a method and a device for determining spatio-temporal evolution of clastic rock diagenetic fluid in a fractured basin. The method for determining spatio-temporal evolution of clastic rock diagenetic fluid in the fractured basin comprises the following steps: acquiring authigenic minerals at different structural positions of the fractured basin; wherein the authigenic minerals comprise carbonate, quartz secondary enlargement and anhydrite; determining the paleofluid temperature of the authigenic mineral according to the uniform temperature of the saline inclusion of the authigenic mineral and the uniform temperature of the hydrocarbon inclusion; and determining the spatio-temporal evolution process of the clastic rock diagenetic fluid of the broken basin according to the paleo-fluid temperature, the predetermined burying history of the broken basin and the paleo-ground temperature gradient. According to the method, the activity time range of diagenesis fluid in clastic rock reservoirs at different structural positions is determined, so that fluid difference evolution modes of different structural positions of the broken lake basin are established, and technical support is finally provided for predicting causes of high-quality clastic rock reservoirs.

The invention belongs to the technical field of exploration and development of fault block oil and gas reservoirs, and particularly relates to a seismic prediction method and system for igneous rock intrusive fault zone sealing performance, and the method comprises the steps: determining the seismic attribute and seismic frequency attribute of a highlight body of a target interval according to petroleum seismic exploration data; determining magma invasion characteristic parameters according to the seismic attribute and the seismic frequency attribute of the highlight body, and determining fracture characteristic parameters of the fracture zone according to an eigenvalue characteristic algorithm operation result in the third-generation coherent attribute of the seismic data; determining an internal structure index of the intrusive fault zone according to the magma invasion characteristic parameters and the fracture characteristic parameters of the fault zone; and comparing the internal structure index of the intrusive fault zone with a closed lower limit threshold of the internal structure index of the known oil reservoir fault zone, and predicting the fault zone closure and the closure capability thereof according to a comparison result, thereby realizing quantitative determination of the oil and gas migration and dredging capability of the fault with magma invasion in the clastic rock stratum.

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 application provides a clastic rock reservoir seismic sequence high-resolution division method and system, S1 obtains the sensitive well logging curve of the well closest to the seismic trace, adopts a cumulative prediction error method to process the sensitive well logging curve to obtain a cumulative prediction error curve, and performs generalized S transformation on the sensitive well logging curve to obtain time-frequency distribution characteristics; S2 performs long-term and short-term cyclic sequence interface identification by using the cumulative prediction error curve and the time-frequency distribution characteristics to obtain long-term and short-term cyclic sequence interfaces; S3 calibrates the long-term and short-term cyclic sequence interfaces to the well seismic trace, performs well seismic trace seismic sequence division, adopts an atomic matching tracking technology to perform well-seismic time-frequency matching analysis in the time-frequency domain, identifies seismic implicit sequence interfaces, and obtains a clastic rock reservoir high-resolution seismic sequence framework after all seismic traces are calculated. The application obtains a high-resolution seismic sequence framework, and provides strong support for improving the precision and accuracy of clastic rock reservoir prediction.

The invention discloses a method for determining a black shale material source carrying path, and relates to the technical field of shale oil and shale gas exploration and development engineering. According to the method, the contents of clay minerals and feldspar are specially selected to be combined with the granularity of shale particles to establish a series of plane contour maps, and through superposition of the plane contour maps, a carrying path with siliceous clastic rock as a main material source, a carrying path with carbonate rock as a main material source and a carrying path of gravity flow are judged; and the carrying path of the black shale of the target layer series in the research area is determined through superposition of the carrying paths. According to the method for determining the carrying path of the black shale material source, the ancient landform of the sedimentary basin can be effectively recovered, an important means is provided for optimization of a favorable shale oil and gas exploration and development area, and then the success rate of well drilling can be effectively increased.

The invention provides a method for improving prediction precision of a deep clastic rock thin reservoir and application of the method, and relates to the technical field of oil exploration and development. The method comprises the following steps of: aiming at a deep clastic rock reservoir section, constructing guided filtering processing on three-dimensional seismic data; then carrying out spectral bluing frequency expansion processing to obtain a processed three-dimensional seismic data volume; carrying out correction and logging rock physical parameter intersection analysis on the logging curve; constructing an isochronous stratigraphic framework model, and using the 90-degree phase rotation three-dimensional seismic data volume to carry out waveform indication inversion; line drawing is carried out on the top and bottom interfaces of the predicted reservoir, interlayer attributes are extracted, and the boundary of the reservoir is depicted finely; and performing time-depth conversion by using the top-bottom interface of the predicted reservoir after line drawing, subtracting the top depth from the bottom depth, and generating a reservoir plane equal-thickness map by using a difference value, thereby realizing plane distribution and feature fine prediction of the complex clastic rock thin reservoir. The matching degree of the prediction result and the actual drilling well is high, and technical support is provided for efficient exploration and development of deep clastic rock oil and gas reservoirs.

The invention relates to a clastic rock reservoir porosity evolution recovery method under a tectonic extrusion background, and belongs to the technical field of petroleum and natural gas exploration and development. The method comprises the following steps: calculating the total compaction pore reduction amount of clastic rock samples, selecting samples with similar burial depths, similar rock structures and different maximum paleotectonic stresses as selected samples, and calculating the total compaction pore reduction amount of the clastic rock samples according to the difference value of the total compaction pore reduction amount corresponding to two selected samples with adjacent maximum paleotectonic stresses. Obtaining the lateral compaction pore reduction amount of the maximum palaeotectonic stress, and establishing a function relationship between the lateral compaction pore reduction amount and the maximum palaeotectonic stress; the lateral compaction hole reduction amount of each time of lateral extrusion in the multiple lateral extrusion processes is calculated; according to the total compaction hole reduction amount and the lateral compaction hole reduction amount, the vertical compaction hole reduction amount is calculated, and a relation chart of the vertical compaction hole reduction amount and the buried depth is established; and drawing a geological historical period porosity evolution curve of the clastic rock reservoir under the tectonic extrusion background by utilizing an inversion back-stripping method and combining the lateral compaction pore reduction amount and the vertical compaction pore reduction amount. The method solves the problem that the lateral and vertical compaction hole reduction amount cannot be quantitatively calculated in the evolution recovery process of the porosity of the foreland basin reservoir.

The invention provides a sedimentary subfacies and microfacies quantitative identification method, and the method comprises the steps: S1, constructing a sedimentary subfacies and sedimentary microfacies database, and determining a sea or lake plane evolution process; s2, establishing a sedimentary concept model, and extracting a data set of virtual well lithology, sedimentary subfacies and sedimentary microfacies; s3, carrying out logging curve forward modeling simulation on the lithology of the virtual well; s4, establishing a discrimination model based on a support vector machine supervision algorithm; s5, verifying the accuracy of the discrimination model; and S6, carrying out sedimentary subfacies and sedimentary microfacies combined judgment on a to-be-evaluated well by utilizing the judgment model to obtain a sedimentary subfacies and sedimentary microfacies judgment result. Batch, efficient and accurate identification of sedimentary subfacies and microfacies of multiple types of clastic rocks can be carried out, the method has important application value for prediction of clastic rock reservoir distribution rules and remaining oil, and meanwhile, favorable technical support is provided for construction of intelligent oil fields and geological large databases.

The invention relates to a clastic rock while-drilling granularity evaluation method based on element logging parameters. The problem of clastic rock reservoir granularity while-drilling analysis is solved by utilizing the element logging parameters. K, Na, Ti, Mn, Ni, Fe and Zr are preferably selected as sensitive parameters for indicating the particle size of the reservoir, a calculation method for the particle size index of the sunken clastic rock reservoir in the West Lake during well logging while drilling is established, and meanwhile, the particle size grading standard of the sunken clastic rock reservoir in the West Lake is established. According to the method, classification while drilling and quantitative evaluation of clastic rock granularity can be rapidly realized, and the method has the advantages of accuracy, rapidness, convenience and low cost.

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 present application relates to a rock porosity calculation method and system based on clastic rock thin section identification data, and belongs to the technical field of oil and gas exploration and geology engineering. The method comprises the following steps: obtaining a first compaction rate according to the carbonate content data in the current clastic rock thin section identification data and the fitting relationship between the carbonate content and the compaction rate in the historical data; obtaining a second compaction rate according to the clay contribution rate obtained from the current clastic rock thin section identification data and the fitting relationship between the clay contribution rate and the compaction rate obtained from the historical data; obtaining a comprehensive compaction rate by weighted average of the first and second compaction rates; obtaining a modified compaction rate by modifying the comprehensive compaction rate according to the ratio of clay to initial porosity and the ratio of carbonate to initial porosity; determining the calculated porosity by using the modified compaction rate; and obtaining the rock porosity by modifying the calculated porosity according to the dissolution and cementation of the thin section. The clay contribution rate is the ratio of the square root of the clay content to the sum of the clay content and the carbonate content.

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).

A method for identifying a tensile-shear fracture in a strong-tectonic extrusion zone clastic rock and related device, comprising: collecting geological data of a well drilling a target layer at a turning end position of an extrusion anticline in a same tectonic belt; determining a homogenized fracture opening degree in a single lithologic layer and a difference between a horizontal maximum principal stress and a vertical stress of the single lithologic layer based on the geological data, drawing an intersection graph, and determining a potential position of tensile-shear fracture development on the intersection graph; verifying the potential position of tensile-shear fracture development on the intersection graph through a tensile-shear fracture identified on a single well core; and determining an identification standard of the tensile-shear fracture based on the verification. The present application calculates in-situ ground stress and the difference between the horizontal maximum principal stress and the vertical stress by using logging data, and identifies the tensile-shear fracture of a well section lacking coring data in a strong-tectonic extrusion zone based on core data verification and the relationship between the normalized fracture opening degree and the corresponding ground stress difference, thereby providing a basis for the prediction and evaluation of the tensile-shear fracture in a similar area.

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 invention discloses a sedimentary clastic rock mineral content prediction method based on an acoustic logging time difference parameter, and relates to the technical field of geophysical research and application, the method comprises the following steps: obtaining the interval transit time value of each measurement point of drilling acoustic logging, and calculating the porosity of a unit layer corresponding to each measurement point of the drilling acoustic logging time difference parameter; correcting the porosity of the unit layer corresponding to each measuring point to obtain a corrected value; constructing a sedimentary clastic rock mineral content prediction model, and inputting the correction value into the sedimentary clastic rock mineral content prediction model to obtain the mineral content of a unit layer corresponding to each measurement point; and based on the mineral content of the unit layer corresponding to each measuring point, the mineral content in the drilling rock stratum is given according to the requirements of different well depth sections. The method solves the problems of complex technology, high cost, long data acquisition period, poor timeliness and the like for acquiring the mineral content in the stratum lithology, can quickly acquire the drill hole carbonate mineral content curve, and is high in refinement degree.

This invention relates to the field of oil and gas field exploration and development, and discloses a logging identification method, system, equipment, and medium for hydrogen-rich reservoirs in clastic rocks. The method includes: identifying oil and gas reservoirs in clastic rock reservoirs based on differences in the conductivity of fluids within the reservoirs; identifying gas reservoirs in clastic rock reservoirs based on differences in the influence of oil and gas on the formation's elastic modulus; and identifying hydrogen-rich reservoirs based on differences in gas density within the gas reservoirs combined with differences in the gas's occurrence environment. The technical solution of this invention comprehensively utilizes logging methods such as shallow and deep resistivity logging, density logging, neutron logging, sonic logging, and natural gamma ray spectroscopy logging to identify hydrogen-rich reservoirs in clastic rock reservoirs, thereby improving the effectiveness and accuracy of hydrogen-rich reservoir identification.

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.

The invention belongs to the field of petroleum and natural gas exploration and development, and particularly discloses a feldspar corrosion effect quantitative evaluation method and system based on a three-end-member chart, and the method comprises the steps: carrying out the statistics of the feldspar corrosion characteristics and product content parameters of a target reservoir; establishing a standardized evaluation chart of the feldspar corrosion effect by taking the volume of a feldspar corrosion pore, the volume of kaolinite and quartz and the volume of illite and quartz as three end members; projecting the counted content parameters into a chart, and determining the feldspar corrosion effect reservoir development types of different zones according to the regional distribution of data points in the chart; the method comprises the following steps: drawing a theoretical linear relation between the feldspar corrosion content and the product content on the basis of a feldspar corrosion theoretical reaction formula, comparing a scatter diagram of actual data with a theoretical line, quantitatively evaluating the corrosion pore increasing or reducing effect through the deviation direction and degree, and further grading and quantifying the reservoir corrosion effect. The deep clastic rock reservoir feldspar corrosion effect evaluation method can perform precise and quantitative evaluation on the deep clastic rock reservoir feldspar corrosion effect.

The invention belongs to the technical field of shale oil and gas exploration and development, and discloses a method for quantitatively characterizing the particle size of clastic particles of clastic rock based on a CT scanning structure image. The method comprises the following steps: firstly, acquiring a geological environment of target layer rock deposition diagenesis, determining image acquisition parameters, and performing multi-scale image acquisition to obtain a grayscale image; then obtaining characterization parameters by using an equivalent sphere algorithm, and constructing a digital model according to a screening standard; building a standard model and a digital result model by means of machine learning; and finally determining a hydrocarbon reservoir dominant reservoir and a fractured target layer section. According to the method, by means of multi-scale image acquisition, machine learning and the like, the accuracy of the three-dimensional digital model of the size and structural characteristics of the clastic particles of the clastic rock is improved, the exploration and development conditions of oil and gas can be predicted more accurately, the exploration and development efficiency is improved, the cost is reduced, and the problem of inaccurate measurement in the prior art is effectively solved.

The disclosed horizontal well guiding method based on multi-disciplinary interaction verification can effectively ensure the successful implementation of the horizontal well in view of the complex geological features such as the heterogeneity of the detrital rock reservoir and the lateral change of the gas layer. In the horizontal well targeting stage, the important adjustment nodes and the reasonable inclination angles thereof are determined, various vertical positioning methods are applied, the step-by-step accurate control of different node positions is realized, and the accurate targeting of the horizontal well is guided and realized. In the horizontal section implementation stage, the deposition model, the three-dimensional seismic model and the three-dimensional geological model of the horizontal section are used to guide the drilling of the horizontal well, and the macroscopic prediction of the seismic targeting and the fine regulation and control of the geological model are realized.

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.

The invention discloses a quantitative evaluation method and device for displacement pressure evolution of clastic rock, and the method comprises the steps: firstly constructing a reservoir pore evolution model according to the original porosity, the surface porosity and the burial evolution history; then, according to the reservoir pore evolution model, establishing a cover layer pore attenuation model; through a mercury injection experiment and porosity analysis regression, establishing a function relationship between the displacement pressure and the porosity as well as between the displacement pressure and the buried depth; according to the statistical displacement pressure and porosity, determining a breakthrough pressure limit between reservoir and cap layers and a limit buried depth of pore response; and finally, based on the function relationship, according to the porosity evolution process and the burial history, inverting the displacement pressure of the cover layer, and obtaining a dynamic evolution curve of the displacement pressure. According to the method, a pore evolution and burial evolution constraint mechanism is introduced, simulation from static parameter analysis to dynamic process is realized, a basis is provided for quantitative analysis of displacement pressure evolution and effectiveness evaluation of a cover layer, and a basis is also provided for a space-time configuration relationship of oil and gas accumulation elements.

The invention provides a carbon-debris-containing clastic rock reservoir oil-water layer geophysical logging identification method. The carbon-debris-containing clastic rock reservoir oil-water layer geophysical logging identification method comprises the steps that 1, the percentage content of carbon debris in rock is obtained; step 2, obtaining the oil saturation in the rock and the effective porosity for removing the influence of the carbon chips; 3, calculating the theoretical resistivity R theory of the stratum by utilizing the porosity and the oil saturation; step 4, obtaining a resistivity correction chart of the formation containing the carbon chips; step 5, performing correction to obtain a resistivity curve R correction without carbon chips; and step 6, establishing an oil-gas-water layer identification chart by using the resistivity curve R correction and the porosity without the influence of the carbon chips. According to the geophysical logging identification method for the oil-water layer of the carbon-chip-containing clastic rock reservoir, the identification accuracy of the oil-water layer of the reservoir is obviously improved, a large number of invalid layer tests are screened out, a huge amount of funds and a large amount of time are saved, and the economic benefits of oil-gas exploration and development 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.