78 results about "Depositional facies" patented technology

The invention discloses a sedimentary facies model construction method and device, equipment and a storage medium. The method comprises the following steps: acquiring regional geological parameters of a target construction region; and determining structure interpretation data according to the regional geological parameters, and constructing a three-dimensional structure model according to the structure interpretation data. And analyzing distribution information of each lithofacies in the three-dimensional structure model according to regional logging data, and constructing a lithofacies framework model. A target sedimentary facies model corresponding to the target construction area is constructed according to the three-dimensional sedimentary point cloud and the lithofacies framework model based on a multi-point geostatistics algorithm, and the three-dimensional sedimentary point cloud is obtained by performing actual sedimentary simulation on the target sedimentary construction model obtained through pre-training based on the area geological parameters of the target construction area. According to the technical scheme, the three-dimensional sedimentary point cloud of the research area can be accurately extracted, high geological objectivity and physical authenticity are achieved, and therefore the objectivity and geological reliability of the sedimentary facies model are remarkably improved.

The invention provides a local artificial intelligence earthquake sand liquefaction deformation prediction method and system, and relates to the technical field of geological disaster prediction, and the method comprises the steps: obtaining multi-source geological data; 3-5Hz soil mass frequency domain features are extracted through wavelet packet decomposition, a DEM and a historical liquefaction thermodynamic diagram are fused to divide a sedimentary facies control unit, a three-dimensional voxel model is generated by adopting a Bayesian constrained improved Kriging algorithm, and a four-dimensional space-time tensor is constructed in combination with real-time seismic oscillation dominant frequency offset; inputting the tensor into a local adaptive graph convolutional network, dynamically adjusting the weight of a convolution kernel through a space-time attention mechanism, and synchronously outputting a prediction result; triggering incremental learning based on MEMS acceleration and FBG strain data, correcting a predicted value of an unliquefied region, and feeding back the predicted value to the voxel model; and finally, generating a probabilistic disaster chain scene tree through spatial pattern matching. The technical bottleneck that a traditional model is poor in adaptability in a complex sedimentary environment and cannot be updated in real time is solved, and intelligent early warning support is provided for engineering safety of an earthquake active area.

This invention provides a method for characterizing sedimentary microfacies distribution based on comprehensive geological and seismic analysis. By studying the sedimentary environment and surrounding tectonic background of the entire block, this invention calculates the cumulative percentage of channel and shoal body types based on sedimentary microfacies and grain size analysis. Based on a comprehensive analysis of the lithofacies of drill cores and corresponding well logging curves and seismic response characteristics, it establishes a comprehensive response model of the main sedimentary facies-well logging facies of the target stratigraphic group in the study area. Furthermore, based on the fusion of seismic attributes, it characterizes sand bodies in seismic profiles. By integrating the sand body characterization results, the comprehensive response model of sedimentary facies-well logging facies, and the sedimentary microfacies types, a method for characterizing sedimentary microfacies distribution in tight sandstone reservoirs using comprehensive seismic and geological analysis is established.

The application discloses a kind of based on sequence stratigraphy and seismic sedimentology's braided river channel reservoir fine characterization method, comprising the following steps: obtaining target area core, well logging and high-resolution three-dimensional seismic data;By analyzing the sedimentology mark and logging facies mark in the target area, to determine the sedimentary facies type and sedimentary microfacies division;Using lithology and well logging curve, using the theory of sedimentology, high-resolution sequence stratigraphy identifies sequence interface type and feature, and carries out high-resolution sequence stratigraphic sequence division;Division reservoir architecture interface;According to the internal structure of sedimentary system, sedimentary facies distribution, focus on high-frequency sequence and sedimentary body scale, generate the braided river channel reservoir fine characterization result of target area architecture unit.The present application effectively solves the deficiencies of prior art in reservoir fine description, boundary identification and parameter inversion, improves the efficiency and success rate of oil and gas reservoir development.

The invention discloses a paleo-gradient constraint reservoir characterization attribute for deep fan delta sedimentary facies characterization. The paleo-gradient constraint reservoir characterization attribute comprises the following steps: 1) carrying out multiple seismic attributes of a target stratum and carrying out normalization processing; 2) seismic attribute optimization is carried out by using the correlation with the sandstone thickness; 3) fitting a multiple linear regression relationship between the sandstone thickness and the optimized seismic attributes; 4) drawing a whole-area sandstone thickness prediction contour map; 5) solving an ancient slope on the ancient landform map; 6) drawing a whole-region ancient slope contour map; 7) acquiring a relation inflection point between the sandstone thickness and the paleo-slope in the research area; 8) predicting sandstone thickness and paleo-gradient by using seismic attributes to establish paleo-gradient constrained reservoir characterization attributes; and 9) calculating all-region paleo-gradient constraint reservoir representation attributes, and drawing a contour map as a basis for depicting the deep fan delta sedimentary facies. The method solves the problem that seismic attribute representation sedimentary facies lacks environmental information and the problem of multiplicity of solutions of deep fan delta seismic reflection representation sedimentary facies.

The invention discloses a method and device for drawing a carbonatite sedimentary facies diagram based on ternary coupling. The method comprises the following steps: determining a water depth environment based on a regional structure effect, a basin position, a substrate characteristic and a climate condition, and establishing a research region concept deposition mode; selecting a typical well, dividing a three-level sequence in the typical well according to earthquake, logging and core data, and further dividing a mapping unit; for each sequence, establishing a relationship between the ternary coupling of the water depth background, the sea level cycle and the paleo-geographic position and the sedimentary hydrodynamic condition and the stratum thickness, analyzing the thickness change of the single well stratum in the sequence, and reversely deducing the sedimentary hydrodynamic condition based on the relationship in combination with the water depth background, the sea level cycle and the paleo-geographic position; and determining a single-well facies under the guidance of the concept sedimentary mode, fitting, matching and correcting the single-well facies and hydrodynamic conditions, and drawing a sedimentary facies diagram of the drawing unit in combination with the regional structure trend. The method can draw a reasonable and accurate regional sedimentary facies diagram for a complex oil field group.

This invention discloses a method for establishing time-spectral sedimentary facies samples based on seismic forward modeling. The method includes: Step S1: Constructing typical sedimentary models and various sedimentary facies property templates for the actual work area based on core sedimentary characteristics; Step S2: Obtaining sedimentary facies geological profiles based on typical sedimentary models and sedimentary facies property templates; Step S3: Extracting actual seismic forward modeling parameters from actual seismic data; Step S4: Conducting forward modeling of the sedimentary facies geological model based on the actual seismic parameters; Step S5: Converting the forward modeled seismic data into time-spectral data through continuous wavelet transform; Step S6: Extracting typical seismic traces from the forward modeled seismic profiles, using the sedimentary facies in the geological model as labels and the time-spectral data as feature values ​​to establish sedimentary facies seismic samples. A large number of high-precision samples are generated under the guidance of typical models, and the sample labels are completely accurate, eliminating errors caused by time-depth calibration, thus meeting the needs of machine learning for sedimentary facies prediction.

The application discloses a kind of seismic facies drive deep carbonate high-precision sedimentary microfacies recovery methods, comprising: basic data collection;Well-seismic calibration;Establish regional isochronous sequence stratigraphic framework;Logging interpretation;Sequence framework within sedimentary facies division: seismic facies division;Establish seismic facies-sedimentary facies conversion relationship;Isochronous sequence stratigraphic framework within division strata slice;Optimization seismic attribute;Establish single factor sedimentary index-seismic attribute relationship;Attribute volume isochronous strata slice;Seismic facies-sedimentary facies under the constraint of high-precision isochronous sedimentary microfacies drawing.The application can accurately predict sequence within sedimentary facies belt boundary by establishing sedimentation-seismic correlation under the condition of less drilling, outcrop;Further optimization can reflect the seismic attribute of sedimentary characteristics, calculate isochronous strata slice;Isochronous sedimentary facies map is obtained by attribute-sedimentary correlation conversion.In practical application, good effect is obtained, and the coincidence rate with actual drilling is high.

The application relates to a method for evaluating a remaining gas sweet spot area of a compact sandstone conglomerate gas reservoir, and belongs to the technical field of oilfield development. The method comprises the following steps: using structures, sedimentary facies and a reservoir model to preferably select a static remaining gas potential area; using a numerical model current pressure and remaining gas abundance to determine a current remaining gas potential area; combining the dynamic and static conditions to preferably select a current remaining gas sweet spot area; carrying out numerical model scheme prediction, using cumulative production, daily production, pressure and remaining gas abundance to determine an optimal scheme; determining a future remaining gas potential area on a pressure and remaining gas abundance diagram predicted by the scheme; combining the dynamic and static conditions to preferably select a future remaining gas sweet spot area; taking the intersection of the current and future remaining gas sweet spot areas to determine a final remaining gas sweet spot area; and deploying a virtual well in the sweet spot area to verify the final remaining gas sweet spot area. The application defines a remaining gas sweet spot area selection method, determines a final remaining gas sweet spot area, and realizes systematic, accurate and rapid selection of a remaining gas sweet spot area of a compact sandstone conglomerate gas reservoir.

The invention belongs to the technical field of oil and gas geological exploration, and particularly relates to a lacustrine facies carbonate rock division method which comprises the following specific steps: selecting a research area with remarkable lacustrine facies mixed deposition characteristics, determining a target interval, and combining a structure location map and a stratigraphic histogram to obtain a lacustrine facies carbonate rock division model; and determining that the sample collection range covers different sedimentary facies zones such as a southern slope zone, a nose-shaped tectonic zone and a northern slope zone. The classification scheme not only has a clear facies indicating significance and can effectively indicate a sedimentary environment, but also provides a reliable lithofacies basis for evaluation of a lacustrine facies carbonate reservoir; the method is especially suitable for oil-gas exploration target optimization under the multi-layer-series and multi-object-source background, and has important practical application value for guiding exploration deployment of similar regions.

The invention relates to the technical field of image synthesis, in particular to a method and device for constructing a superimposed sedimentary facies belt graph at a sedimentary unit level, and the method comprises the steps: obtaining multi-source information data of a target oil field; constructing a three-dimensional space distribution model based on the multi-source information data; obtaining isoline data and fault polygon data based on the three-dimensional space distribution model; obtaining the smoothed isoline data; obtaining corrected fault polygon data; splitting the combined fault polygon into a plurality of fault independent units; generating fault polygon data with upper and lower wall marks; obtaining a deposition unit level structure map of the target layer; obtaining a sedimentary facies belt graph of the target layer; and taking the sedimentary unit level structure map and the sedimentary facies belt map of the target layer as different map layers for superposition to obtain a plane structure map of the target layer. According to the method, the requirement of development field personnel for quickly drawing a two-dimensional plane graph with fault hanging and footwall and sedimentary facies distribution can be met.

The present application provides a kind of carbonate rock thin reservoir interwell connectivity evaluation method, comprising the following steps: (1) collecting the regional geological background of the purpose layer of the study area in multiple wells, drilling and logging data, seismic data, production dynamic data, and establishing database;(2) determine the sedimentary facies type, determine the reservoir characteristics;(3) the logging data of different wells is normalized, and the logging sequence is combined to form the logging facies, and the logging facies characteristics of the corresponding reservoir section between adjacent wells are compared;(4) obtain the pressure coefficient of adjacent wells at the same altitude depth, and compare the pressure coefficient of the corresponding reservoir section between adjacent wells;(5) according to the seismic phase profile and seismic phase plane of the well, the phase change of the corresponding reservoir section between adjacent wells is compared;(6) according to the comparison result, judge whether the thin reservoir is connected or not.The beneficial effects of the present application: can carry out static productivity prediction in newly drilled carbonate reservoir, and then provide reference for well completion test.

The present application relates to the field of oil and gas exploration, and provides a few well area multi-depositional facies belt sand shale reservoir prediction method and system, the method comprises the following steps: preprocessing seismic exploration data of the study area, extracting seismic attribute volume combined with depositional facies belt lithology difference, screening the seismic attribute volume through lithology sensitivity analysis to obtain core attribute volume; taking the core attribute volume as a constraint condition, performing primary inversion on the pretreated seismic exploration data through inversion algorithm to obtain primary inversion data volume; constructing pseudo well according to the primary inversion data volume and depositional facies belt characteristics, modeling the pseudo well and well logging data of real drilled well jointly to obtain low frequency model; taking the low frequency model as a constraint condition to perform iterative inversion, predicting sand shale reservoir from the iterative inversion result to obtain full area sand shale reservoir prediction result. The present application improves the adaptability of multi-depositional facies belt.

The invention relates to the technical field of oil-gas exploration, in particular to a lithologic trap evaluation method, device and equipment, a medium and a computer program.The method comprises the steps that under the condition that a sedimentary facies type is a single-well sedimentary facies, a seismic facies plane distribution diagram corresponding to a target area is obtained; based on the first corresponding relation and the seismic facies plane distribution diagram, obtaining a reservoir porosity plane distribution diagram; based on the second corresponding relation and the seismic facies plane distribution diagram, a packing layer porosity plane distribution diagram is obtained; and determining an evaluation result of the lithologic trap based on the seismic facies plane distribution, the reservoir porosity plane distribution diagram and the packing layer porosity plane distribution diagram. According to the method, when the distribution of the reservoir and the packing layer is predicted, the wave impedance corresponding to the porosity is considered, quantitative prediction is achieved, the evaluation result of the lithologic trap is obtained based on the distribution conditions of the seismic facies, the reservoir and the packing layer, the accuracy of the evaluation result of the lithologic trap is improved, and then the exploration success rate of the lithologic trap is improved.

Disclosed is a method for deposition formation of deposits within an immersion region, comprising:-receiving a sedimentary facies classification and a sedimentary environment classification; -simulating the evolution of the topography of the submerged deposition area over time, comprising: defining a model of the submerged deposition area, the model having an earth surface, a plurality of deposit supply or generation processes and at least one water flow to be simulated; simulating a formation in which at least one deposit is deposited on the earth surface over a time period, including: introducing particulate deposits into a model; conveying at least one particle by applying a water flow, wherein the conveying comprises displacing or depositing the particle onto the earth surface; and recording data about the deposited particles; and updating the terrain of the earth surface. For at least one unit of the sedimentary formation, associating the unit with the sedimentary facies and the sedimentary environment based on a comparison of the recorded data with the sedimentary facies classification and the sedimentary environment classification.

The application discloses a sedimentary reservoir prediction method based on three-dimensional seismic data, which comprises the following steps: step one, feature extraction; step two, feature dynamic fusion; step three, model establishment and training; step four, optimization of storage prediction results; and step five, visualization interaction. The system comprises a data processing module, a feature fusion module, a model training module, a reservoir prediction module and a visualization interaction module. The dynamic weight distribution algorithm is used to fuse multi-dimensional features such as seismic waveforms, frequency spectra and geometric attributes, so that the vertical resolution of thin interbedded layers is significantly improved, the identification difficulty of hidden reservoirs is solved, and the loss risk is reduced. A double-channel neural network model is established to automatically extract seismic features and sedimentary facies knowledge, so that the deviation of artificial feature engineering is avoided, the rapid modeling demand of a complex sedimentary environment is met, and the prediction results are constrained and corrected, so that the continuity of a vertical sedimentary sequence is ensured.

The invention relates to the technical field of deep oil and gas exploration, in particular to a deep reservoir dominant region prediction method and device, and the corresponding method comprises the steps: determining a reservoir sedimentary facies diagram of a deep reservoir through the sedimentary structures and sedimentary facies of a plurality of single-well reservoirs under the constraint of a pre-generated sedimentary-structure pattern diagram of the deep reservoir; wherein the sedimentary facies is a superposed part of an early-stage high-quality facies belt and a diagenetic facies belt in a quasi-synbiotic period of the deep reservoir; determining a reservoir diagenetic phase diagram of the deep reservoir according to a pre-generated diagenetic sequence diagram of the deep reservoir, the corrosion landform partition map and the fluid system plane distribution diagram; and according to the reservoir sedimentary facies map, the reservoir diagenetic facies map, the dominant sedimentary facies and the dominant diagenetic facies, predicting the dominant region of the deep reservoir. According to the method, the viewpoint of controlling the scale high-quality reservoir by the early-stage high-quality facies belt and the quasi-synbiotic lithogenous facies belt is provided, the double-phase superimposed belt control and reservoir model is established, deep reservoir prediction is carried out, and a good effect is achieved.

The present disclosure relates to a sandstone thickness mapping method, system, electronic device and storage medium. The mapping method comprises: obtaining logging data of each well point in a preset area, and determining sandstone and mudstone lithological characteristic data according to the logging data; determining sandstone curve shape and sandstone thickness of each well point according to the sandstone and mudstone lithological characteristic data, and mapping a sedimentary facies pattern of the preset area through the sandstone curve shape and the sandstone thickness; converting the sedimentary facies pattern to a constraint plane for determining the trend change of a sedimentary facies belt in a three-dimensional geological framework model plane range; generating plane sandstone thickness data through the constraint plane based on a geostatistical stochastic simulation algorithm, and mapping a sandstone thickness map of the preset area according to the plane sandstone thickness data. The sandstone thickness is generated by combining the geological statistical principle and the sedimentary facies pattern, and the sandstone thickness map is mapped according to the sandstone thickness, so that high-precision prediction and visual expression of the sandstone thickness are realized.

The invention relates to a sweet spot reservoir prediction method based on source-sink-rock system coupling, and the method comprises the steps: constructing a sequence framework which comprises the steps: recognizing a single well sequence interface, carrying out the seismic sequence division of the sequence interface, and verifying the sequence interface through ancient biology; in the sequence framework, material source supply capacity calculation is carried out, a material source judgment system, an ancient landform recovery result and seismic attribute analysis are synthesized, sedimentary system distribution characteristics are identified, sedimentary facies belt prediction is carried out, and a sedimentary facies control sand body model is established; establishing a three-dimensional sand body distribution model based on the sequence framework, the distribution characteristics of the sedimentary system and the sedimentary facies control sand body model; a favorable zone is obtained through prediction according to seismic attributes of all system domains in the multiple sets of sand-rich deposition system distribution feature superposition coupling sequence grillages; and based on the three-dimensional sand body distribution model, and in combination with a reservoir diagenesis-physical property corresponding relationship summarized by single well actual measurement data, preferably selecting a sweet spot target in the favorable zone. According to the invention, the reliability of sweet spot reservoir prediction can be improved.

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 provides a method for deploying a deep low-permeability reservoir well location in a low-exploration-degree area. The method comprises the steps that the source, sedimentary facies, fault characteristics and sand body distribution characteristics of a target area are analyzed; according to analysis results of material sources, sedimentary facies, fault features and sand body distribution features, an exploration area sedimentary mode is established, and an exploration favorable area is determined; and drilling target evaluation is carried out on the exploration favorable area, a reservoir forming mode is established, and a well location deployment scheme is determined. According to the method, a sedimentary mode is established and a favorable area is optimized by analyzing object sources, sedimentary facies, fault characteristics and sand body distribution characteristics, and then drilling target evaluation, reservoir forming mode establishment and well location deployment scheme determination are carried out on the favorable area. According to the method, interference of complicated analysis means is removed, analysis of key problems is mainly mastered, the accuracy and efficiency of evaluation are improved, and the accuracy is improved by 50% and reaches 95%; the working efficiency is improved, invalid work is avoided, the workload of five persons and 60 days is reduced to be completed by four persons and 30 days, and deployment of the deep low-seepage well position is assisted.

The invention discloses a sedimentary facies mapping method based on well control seismic attributes under a sparse well pattern condition, and the method comprises the steps: judging a sedimentary facies type of a target layer section, and determining a sedimentary microfacies unit of the sedimentary facies; determining the type of a sedimentary microfacies unit of each well, and calculating the sand content of each well; extracting seismic attributes of a target layer section; establishing a well point sand ratio and seismic attribute regression equation; thinning the seismic data according to the actual well spacing to serve as a virtual well point, and converting the seismic attributes into the sand content to obtain the sand content of the virtual well point; a plane sand ratio contour map is obtained by combining actual well points; determining a standard sand ratio range corresponding to each sedimentary microfacies unit according to the actual well point; and drawing a sedimentary facies diagram according to the sand content threshold values corresponding to different sedimentary microfacies units. According to the method, the quantitative relation among the well point data, the seismic data and the sedimentary facies is established, the defect of a sparse well pattern on sedimentary facies distribution prediction is made up by utilizing the high-density characteristic of seismic data plane data, and effective prediction of a plane facies belt can be achieved to the maximum extent.

This invention belongs to the field of reservoir prediction technology, specifically seismic inversion, and particularly relates to a method and apparatus for establishing an initial facies-controlled model in facies-controlled inversion. Based on sedimentary facies, this invention establishes a forward model and performs forward analysis according to the lithological combination characteristics and variation patterns of different facies zones. It then selects seismic attributes or attribute combinations that can distinguish different facies zones to establish seismic identification models for different sedimentary facies. These identification models are used to classify seismic facies, and the seismic facies control the establishment of the subsequent initial model, thereby making the initial model more reasonable and more sedimentary indicative.

The invention provides a reservoir quantitative evaluation method and device of a mixed deposition system and a medium, and relates to the technical field of petroleum and natural gas exploration, the method comprises the following steps: obtaining geological data of the mixed deposition system, the geological data comprising first geological data, second geological data and third geological data; determining a favorable sedimentary facies corresponding to a main sedimentary system in the mixed sedimentary system according to the first geological data and the second geological data; determining a target plane distribution diagram of the favorable sedimentary facies according to the second geological data and the third geological data; and according to the target plane distribution diagram, the second geological data and the third geological data, determining the distribution range and thickness of the reservoir to quantitatively evaluate the reservoir. Therefore, quantitative evaluation of the reservoir of the mixed deposition system is realized, the accuracy of quantitative evaluation of the reservoir is improved, an effective and feasible means is provided for solving the problem of quantitative evaluation of the reservoir in the mixed deposition system, and breakthrough of oil-gas exploration in a low-exploration-degree area is facilitated.

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 fractured tight oil reservoir saturation modeling method. The method comprises the following steps that S100, a well-seismic combined structure fault model is established; s200, under the constraint of a sedimentary facies mode, utilizing a single well facies as hard data in the longitudinal direction and data analysis according to a variation function on a plane as guidance, applying an SIS random algorithm to simulate sandstone facies distribution, and establishing a sandstone-mudstone spatial distribution model; s300, based on the seismic fusion attribute three-dimensional body and the sandstone three-dimensional model, establishing a fracture phase three-dimensional geologic model; s400, establishing a fault distance-saturation function through a fitting method, and establishing an oil saturation three-dimensional geologic model according to the function; compared with a traditional saturation modeling method, the saturation model established through the method has the advantages that the control effect of fracture on the oil-water distribution rule is described more accurately, the coincidence rate of the saturation model established through the method is 90% compared with that of a real drilled well, a good oil reservoir geologic model is provided for numerical simulation, and the development effect of an oil field is improved.

This invention relates to the field of oilfield development technology and discloses a well-seismic combined method for reorganizing reservoir stratigraphy in sandstone oilfields, comprising the following steps: S1, acquiring well logging data, seismic data, and geological data to establish a high-resolution sequence stratigraphic framework; S2, using well-seismic combined technology to draw sedimentary facies maps and identify the distribution characteristics and development differences of reservoir sand bodies; S3, analyzing the dynamic development effect of the reservoir, including water cut, recovery rate, and remaining oil distribution development indicators; S4, optimizing the stratigraphic combination method, sealing high water-cut layers, and reorganizing effective development stratigraphic layers; S5, adjusting the well network deployment, combining new drilling and old well conversion for injection, and optimizing well spacing and injection-production relationship. By using well-seismic combined technology to finely segment reservoirs, optimize stratigraphic layers and injection-production well network deployment, and combine dynamic monitoring to adjust injection-production configuration in real time, the problem of inter-layer interference is solved, water injection displacement efficiency is improved, and high efficiency and stability of oilfield development are achieved.

This invention belongs to the field of oil and gas seismic exploration and development, specifically disclosing a well-seismic combined sedimentary facies modeling method, system, equipment, and medium. The method includes: S1, determining the planar distribution of lithofacies and sedimentary facies in a single well; S2, performing synthetic record calibration by combining 3D seismic data; S3, clustering and classifying seismic waveforms of geological target layers based on the characteristics of well-side seismic data, and establishing a sedimentary facies label library associated with well logging; S4, constructing a neural network prediction model and training the model; S5, inputting 3D seismic data and well logging data of the target area into the trained neural network prediction model, and outputting the planar distribution of sedimentary facies; S6, correcting the planar distribution of sedimentary facies using well logging facies samples at the well points to obtain the spatial distribution of sedimentary facies. This invention effectively utilizes well-seismic data, improving the accuracy of sedimentary facies identification. This invention is suitable for characterizing the spatial distribution of sedimentary facies.

This disclosure relates to the field of oil and gas geophysical exploration technology, and particularly to a method, apparatus, and computer-readable storage medium for inverting elastic parameters. The method involves acquiring seismic data volumes and sedimentary facies maps of the study area, as well as drilling data from adjacent study areas. The drilling data includes: well logging data from the wells; determining, based on the sedimentary facies map, well logging data matching the characteristics of each sedimentary facies zone in the study area as virtual well logging data; determining the optimal location of virtual wells within each sedimentary facies zone; determining the elastic parameter curves of each virtual well based on the logging data of each virtual well; establishing a facies-controlled low-frequency model of elastic parameters under both longitudinal and transverse constraints based on the optimal location of each virtual well and the corresponding elastic parameter curves; and performing pre-stack facies-controlled inversion based on the seismic data volume and the facies-controlled low-frequency model to obtain the inversion results of the elastic parameters. This method can obtain elastic parameter inversion results in low-exploration areas that better conform to actual geological sedimentary patterns, thereby more accurately characterizing the distribution features of sand bodies.

The invention discloses a multi-cycle structure deposition process identification method based on physical simulation of a growth stratum sand box, and relates to the technical field of deposition analysis, geological data of a target area are obtained, and the geological data comprise stratum thickness, sediment type and structure characteristics; based on current stratum thickness equal-proportion conversion, a growth stratum sand box physical model is established. The dynamic coupling relation between tectonic deformation and deposition filling is visually revealed through physical simulation of the growth stratum sand box, so that a researcher can directly observe how the tectonic activity affects the distribution and accumulation mode of sediments and how the deposition action is fed back to act on the tectonic deformation process; the method overcomes the limitation that the traditional geological survey method is difficult to comprehensively reveal the structure-deposition interaction, provides a powerful tool for deeply understanding the multi-cycle structure deposition process, not only enhances the intuition of geology research, but also improves the analysis capability of complex geological phenomena.