149 results about "Facies" patented technology

The invention provides a method and a device for establishing a three-dimensional sandstone probability body. The method comprises the following steps: integrating a well-seismic database; constructing a three-dimensional construction framework model; converting the time domain seismic data volume into a depth domain seismic data volume; extracting a target seismic attribute according to a preset rule; sampling a target seismic attribute to a three-dimensional construction framework model; performing multi-attribute clustering fusion on the seismic attribute values of the three-dimensional construction framework model by using a preset neural network model, and establishing a sedimentary unit model; calculating a variation function between the sandstone content data for each partition of the sedimentary unit model; and performing interpolation by using a Kriging algorithm, and predicting the sandstone content of an unknown point to obtain a three-dimensional sandstone probability body model. According to the method, a multi-type and multi-attribute fused three-dimensional sandstone probability body is established, the value type of reservoir facies and the value of reservoir parameters are constrained by endowing each grid with a probability value, and reliable trend constraint conditions are provided for geologic modeling of low-well-control and strong-heterogeneous reservoirs.

The invention relates to the technical field of oil exploration, and discloses a rock mechanical parameter logging intelligent evaluation method considering continental facies shale fabric characteristics. The method comprises the following steps: 1, dividing shale lithofacies, identifying and determining the bedding development thickness of a sample through an optical microscope, determining a granularity experiment of the sample through granularity analysis, and forming mineral composition and bedding factor lithofacies division; 2, constructing a typical logging facies based on a rock electricity response relationship, and dividing the imaging logging facies of the research area according to natural gamma curves of conventional logging and imaging logging, core deposition structure characteristics and imaging logging image characteristics; 3, testing the longitudinal and transverse wave velocities and the porosity of different shale lithofacies, and calculating the dynamic elastic modulus and the Poisson's ratio. Through fine division and description, the method for accurately evaluating the bedding development condition, the particle size characteristics and the mineral components of the shale sample is provided, the testing time is short, the cost is low, and accurate evaluation of shale can be achieved.

The invention provides a high-precision recovery method and system for judging the sedimentary environment of marine facies mixed-volume shale, which is characterized in that on the basis of microscopic slice fine identification, the types of minerals in a sample are preliminarily identified by XRD (X-Ray Diffraction), the mineral color change under a cathode luminescence test is combined, and the mineral composition is analyzed by XRD; three main end members of carbonate minerals, clay minerals and siliceous minerals are used for triangular projection so as to identify main lithofacies types of the mixed-volume shale and plane distribution characteristics of various lithofacies; through TOF-SIMS, micro-area mineral composition and micro-area element change identification in the mixed shale is carried out, and a biomarker compound in organic geochemistry is used for sedimentary environment identification, so that sedimentary environment change corresponding to complex lithofacies change of the mixed shale is identified, and the formation mechanism of the mixed shale is clarified.

The invention provides a method for quantitatively evaluating the paleo-productivity of hydrocarbon source rock in a sedimentary period. The method comprises the following steps: acquiring a representative rock sample in a target hydrocarbon source rock stratum; carrying out total organic carbon content test, total rock mineral composition analysis and organic petrology analysis on the selected rock sample; determining the deposition rate of the rock sample in the deposition period; and establishing a quantitative evaluation model for the ancient productivity in the deposition period based on a carbon element substance conservation principle. The method for evaluating the ancient productivity is based on the principle of conservation of carbon elements, and the ancient productivity of hydrocarbon source rocks is quantitatively evaluated through the steps of organic matter thermal evolution hydrocarbon generation recovery, organic matter anaerobic oxidation consumption recovery, terrestrial source organic matter input and removal and the like. The method is widely applied to ancient productivity evaluation of hydrocarbon source rocks in marine facies and continental sedimentary environments in different regions, and provides technical support for formation mechanism research and distribution prediction of continental facies high-quality hydrocarbon source rocks in China.

The invention discloses a comprehensive source discrimination method suitable for a complex clastic rock system, and relates to the technical field of petroleum and natural gas exploration and development. According to the method, the space imaging advantage of three-dimensional seismic data of a research work area on an underground geologic body is fully utilized, and the material source of a complex clastic rock system is comprehensively judged by recognizing the carrying process of sedimentary substances and combining the datum plane cycle, logging facies and rock facies achievements. According to the method, the carrying process of the sediment can be more effectively highlighted, and interpretation personnel can be helped to more effectively clarify a material source system. The method disclosed by the invention is suitable for comprehensive distinguishing research on the material sources of the complex clastic rock system, and is expected to be applied to lithofacies paleogeography recovery and mineral resource development of a multi-material-source system basin.

The invention discloses a salt lake carbonate rock multi-parameter quantitative classification and reservoir evaluation method, and relates to the technical field of oil-gas exploration. The method comprises the following steps: selecting a key well in an exploration block, collecting a plurality of salt lake carbonate rock samples, preparing an analysis sample under an anhydrous condition, quantitatively measuring a salinity parameter, a mixing index and a diagenesis strength parameter by utilizing the analysis sample, and determining a salinity code, a mixing code and a diagenesis phase code. And naming the salt lake carbonate rock based on the salinity code, the mixed product code and the lithogenous phase code, directly evaluating the salt lake carbonate rock reservoir according to a naming result, and performing single well comprehensive evaluation on the salt lake carbonate rock reservoir. According to the method, the influence of salinity, mixed accumulation and diagenesis strength on formation and evolution of the salt lake carbonate rocks is fully considered, accurate division of the types of the salt lake carbonate rocks is achieved, the reservoir naming result is directly associated with reservoir evaluation, and technical support is provided for standardized evaluation of the salt lake carbonate reservoir.

The invention discloses a shale lithology identification method based on a prior Bayesian cascade forest, and relates to the field of rocks, the shale lithology identification method based on the prior Bayesian cascade forest comprises the following steps: 1, firstly establishing a mineral pre-training model data set of continental facies shale, then taking logging data in the data set as features, and taking the logging data as the features; taking the mineral data as a label, using a Bayesian extreme gradient lifting regression device for training, and storing a mineral pre-training model; compared with the prior art, the method has the advantages that the class imbalance problem of logging data is considered, self-adaptive multi-target group fusion is used for resampling a data set, X-ray diffraction total rock mineral analysis data is used, feature generation is carried out by means of a Bayesian gradient lifting regression device, and the method is high in accuracy and high in accuracy. And then the Bayesian gradient lifting classifier is used for identifying the shale lithology, so that the cost is low under the condition of high accuracy, and a reliable scheme is provided for identifying the shale lithology.

The invention relates to a construction method, device, equipment and medium of a complex geological reservoir model, and relates to the technical field of oil exploration and development. Comprising the following steps: combining obtained riverway scale parameter data obtained by field actual measurement, a three-dimensional digital outcrop profile of an outcrop profile of a research area, a geological knowledge database of configuration units at all levels of a sub-facies reservoir of the research area, and sedimentary microfacies distribution of the outcrop profile of the research area obtained by combining the riverway scale parameter data to obtain X, Y, Z, Z, Z and Z; performing two-dimensional training image slicing in three directions of Z and Z; and performing three-dimensional training image simulation on the two-dimensional training image slices by using an s2Dcd-DS coupling algorithm, and performing three-dimensional geological modeling by using a multi-point geostatistics modeling algorithm to obtain a three-dimensional geological model. According to the construction method provided by the invention, the complex geological conditions and structural characteristics of the complex geological reservoir such as the plains of the braided river delta can be effectively represented, and oil and gas distribution, well location deployment and remaining oil excavation of the braided river reservoir can be guided.

The invention discloses a marine hydrocarbon source rock thickness plane distribution prediction method, device and equipment and a medium. The method comprises the following steps: acquiring a marine facies hydrocarbon source rock core of a to-be-researched area, and determining a logging curve corresponding to the marine facies hydrocarbon source rock core and a development interval range of the marine facies hydrocarbon source rock; and on the basis of the logging curve and the development interval of the marine hydrocarbon source rock, constructing a marine hydrocarbon source rock logging identification quantity version. And carrying out seismic inversion based on the marine facies hydrocarbon source rock logging identification quantity version to obtain a two-dimensional inversion seismic section, and determining the hydrocarbon source rock thickness of the marine facies hydrocarbon source rock based on the two-dimensional inversion seismic section. And through seismic horizon calibration, according to the hydrocarbon source rock thickness, determining predicted marine facies hydrocarbon source rock thickness plane distribution corresponding to the marine facies hydrocarbon source rock in the to-be-researched area, thereby making up the limitation of marine facies hydrocarbon source rock distribution prediction by singly using seismic data, and improving the accuracy of hydrocarbon source rock plane distribution prediction at the same time.

The embodiment of the invention provides a method and device for obtaining the stratum penetrating position of a well track of a continental facies shale horizontal well. The method comprises the steps that geological parameters and engineering parameters of all small stratums of continental facies shale are obtained; hydraulic fracturing fracture morphological parameters are determined according to the geological parameters, the engineering parameters and the hydraulic fracturing process parameters; according to the hydraulic fracturing fracture morphological parameters, the propping agent stacking height of the continental facies shale under different horizontal well track layer penetrating positions is determined, and the supporting condition in the fracture height direction is evaluated according to the propping agent stacking height; and according to the hydraulic fracturing fracture morphological parameters and the supporting condition in the fracture height direction, the final horizontal well hole track layer penetrating position is determined. By means of the method, the high-quality borehole crossing position can be obtained and used for guiding drilling design and development of the continental facies shale horizontal well.

Methods and systems are configured for accessing a three-dimensional (3D) facies model including a set of layers, each layer including boundaries data representing initial facies boundaries for a set of facies represented in that layer; accessing geological constraints data representing facies trends for the set of facies represented in the facies model; for each layer: for each facies type in the layer, determining, for a portion of the layer, a distance from the portion of the layer to a facies boundary for that facies type in the layer; and based on the distance for each facies type and the facies trends represented in the geological constraints data, determining a facies probability value; stacking the layers each including facies probability values for each facies type represented in that layer; simulating facies trends for each facies type; and generating a 3D facies trend model including the simulated facies trends.

A method for recognizing a dominant carbonate rock reservoir in a complex facies zone, comprising: determining a lithologic type and lithologic physical properties of a study section (S100); carving out a development pattern configuration of a special geologic body in the lithologic type (S200); on the basis of the development pattern configuration, using an iterative modeling method to construct an inversion low-frequency model under a phase controlled constraint (S300); using the inversion low-frequency model to perform multi-parameter pre-stack inversion of the study section to obtain an inversion parameter data volume of the study section (S400); and using a multi-parameter intersection method to predict a dominant reservoir distribution in the inversion parameter data volume (S500). Also provided are an apparatus for recognizing a dominant carbonate rock reservoir in a complex facies zone, and an electronic device. By means of the phase controlled constraint, a configuration attribute representing geomorphic facies and lithologic inversion representing lithologic facies are comprehensively considered, and the attribute lateral resolution and the inversion longitudinal resolution are combined, thereby achieving high-precision recognition of a dominant carbonate rock reservoir in a complex facies zone.

The invention discloses a method for molding a near-source phase, a middle-source phase and a far-source phase of a volcanic institution, and the method comprises the steps: S1, constructing a three-dimensional digital model of the volcanic institution in a to-be-simulated region, and the three-dimensional digital model comprises a near-source phase belt digital model, a middle-source phase belt digital model and a far-source phase belt digital model; s2, selecting a high-speed material, and crushing and screening the high-speed material to obtain high-speed material powder; wherein the speed of the high-speed material is 200-400m / s higher than that of the volcanic mechanism overflow phase, and the density of the high-speed material is greater than that of the volcanic mechanism overflow phase And S3, the obtained high-speed material powder is adopted, a composition containing epoxy resin serves as an overflow phase for casting molding, three-dimensional carving is conducted according to the obtained near-source phase belt digital model, the obtained middle-source phase belt digital model and the obtained far-source phase belt digital model, and a near-source phase belt model, a middle-source phase belt model and a far-source phase belt model are manufactured respectively. The molding method disclosed by the invention is more intuitive and accurate and has higher modifiability.

The invention provides a method and system for identifying a volcanic institution facies belt boundary, and belongs to the technical field of oil exploration and development. The method comprises the following steps: dividing a drilled facies belt according to three-dimensional seismic reflection characteristics and a preset type of lithofacies proportion of a drilled well; constructing a near-source facies belt pseudo well and a far-source facies belt pseudo well based on the division result of the drilled facies belt and the multiple types of drilled lithofacies; based on the near-source facies zone pseudo well and the far-source facies zone pseudo well, determining a value range corresponding to a preset type of lithofacies proportion of the volcanic institution; based on the three-dimensional seismic data volume of the volcanic institution, a planar graph representing a facies belt is obtained; according to the value range corresponding to the preset type lithofacies proportion of the volcanic institution, volcanic institution facies belt division is carried out on the planar graph representing the facies belt, and the boundary between the near-source facies belt and the far-source facies belt is obtained. Therefore, the boundary between the near-source phase belt and the far-source phase belt is accurately and effectively defined, the near-source favorable phase belt of the volcanic institution is quickly focused, and a foundation is laid for an exploration target.

The invention discloses a fractured-vuggy reservoir rock facies fine division method. The method comprises the steps that single well data of a to-be-measured area is acquired and preprocessed; carrying out depth homing on the required core physical property data; performing principal component analysis on the single well data to obtain dimension reduction and noise reduction fusion representation data; the data set is divided into a clustering data set and an inspection data set; carrying out optimal classification cluster selection on the clustering data set by adopting an elbow rule; classifying the data by adopting a fuzzy C-means improved clustering algorithm, and establishing an identification model of the fractured-vuggy reservoir rock facies; evaluating the identification model of the fractured-vuggy reservoir rock facies by adopting the contour coefficient; the identification model of the fractured-vuggy reservoir rock facies is inspected in combination with the inspection data set; outputting a test clustering result by using the test identification model of the fractured-vuggy reservoir rock facies, and performing sensitivity analysis by using a rank correlation matrix; and intersection is carried out by adopting the sensitive curves to obtain an identification chart of the fracture-vuggy reservoir rock facies.

The invention relates to the technical field of lithofacies paleogeography and reservoir geology, in particular to a carbonate rock large-scale high-quality reservoir quantitative geological evaluation method, which comprises the following steps of: 1, determining compilation of a carbonate rock lithofacies base map; 2, identifying a carbonate rock paleogeographic pattern and a high-quality reservoir facies belt; 3, quantitatively depicting a high-quality reservoir sedimentary body, and expressing a geologic body structure; 4, judging the type of the storage space; and 5, analyzing the diagenesis and diagenesis sequence of the large-scale reservoir. According to the method, quantitative geological evaluation of the large-scale high-quality reservoir of the carbonate rock can be well carried out.

The invention provides a method for recovering the maximum ancient ground temperature and regional thermal history of a marine facies or lacustrine facies sedimentary area. The method comprises the following steps: (1) selecting a carbonate sample, and carrying out effectiveness analysis on the carbonate sample to obtain a hydrocarbon source rock maturity test sample and a paleo-thermal history research sample; (2) performing pretreatment on the hydrocarbon source rock maturity test sample and the paleo-thermal history research sample obtained in the step (1), and then performing carbonate cluster isotope composition analysis and data validity selection to obtain test data; and (3) recovering the paleo-temperature and / or regional thermal history according to the available data obtained in the step (2). According to the method, the maturity (suffered maximum paleo temperature) of marine facies / lacustrine facies hydrocarbon source rocks is recovered by utilizing a cluster isotope method of carbonate of a hydrocarbon source rock interlayer or an adjacent layer, and a large set of well preserved carbonate samples is used for a regional paleo thermal history recovery technology, so that a basis is provided for realizing oil and gas resource evaluation and aggregation rule prediction; the method is greatly helpful for exploration of shale oil and gas and deep / ultra-deep oil and gas.

The methods may include defining cells that represent a subterranean region of interest (SROI) and obtaining seismic data and well data pertaining to the SROI. Each cell is associated with a location within the SROI and seismic constraint among the seismic data. The cells include informed cells and uninformed cells. Each informed cell is associated with each well datum. The methods may further include obtaining a process-based geological model (PBGM) of the SROI and determining a corresponding simulated seismic image (CSSI) based on the PBGM. Each cell is further associated with a facies among the PBGM and simulated seismic constraint among the CSSI. The methods may further still include determining a probability based on the location, seismic constraint, PBGM, CSSI, and well data for each uninformed cell, determining a seismic-conditioned PBGM based on the probabilities, and identifying a predicted location of hydrocarbons within the SROI based on the seismic-conditioned PBGM.

A system and method for performing a reservoir evaluation are disclosed. The method includes obtaining a nuclear magnetic resonance (NMR) dataset for a plurality of samples and obtaining an NMR log for a wellbore penetrating a reservoir. The method further includes determining a rock facies description for each sample, determining an NMR transverse relaxation time (NMR T2) distribution from the NMR dataset, and determining a set of parameters characterizing the NMR T2 distribution based on one or more predetermined parameters. The method still further includes identifying a plurality of NMR facies based, at least in part, on the set of parameters for each sample, determining a transformation that maps a subset of rock facies to a subset of the plurality of NMR facies, and performing the reservoir evaluation based, at least in part, on applying the transformation to the NMR log.

The invention discloses a reservoir plane distribution feature fine description method based on landform control, and the method comprises the steps: carrying out fine well-seismic calibration based on three-dimensional seismic data and well-seismic combination, and tracking and explaining a top interface and a bottom interface of a target reservoir; calculating an initial reservoir sensitive seismic attribute; obtaining a target reservoir deposition ancient landform; according to the fine well-seismic calibration time-depth relation, the current terrain of the target reservoir is obtained; and correcting the initial reservoir sensitive seismic attribute according to the target reservoir sedimentary ancient landform and the current terrain of the target reservoir to obtain a final target reservoir sensitive seismic attribute, and compiling a target reservoir sedimentary facies map according to the final target reservoir sensitive seismic attribute. Aiming at the reservoir characteristic analysis uncertainty caused by strong reflection of the substrate and the gas-bearing reservoir, the method for correcting the sensitive seismic attributes of the reservoir by adopting the ancient landform and the current topography is adopted, the reservoir response error information caused by strong reflection of the substrate and the gas-bearing reservoir is eliminated, the reservoir characterization precision is improved, and the reservoir analysis uncertainty is effectively reduced.

The invention provides a sedimentary diagenesis facies seismic geology combined prediction method. The prediction method comprises the steps that S1, reservoir parameters and reservoir diagenesis facies types corresponding to reservoir core slices are determined; s2, determining pore structure types of multiple types of lithogenous phases; s3, classifying the sedimentary diagenetic facies, and dividing the sedimentary diagenetic facies into favorable sedimentary diagenetic facies and secondary favorable sedimentary diagenetic facies; s4, establishing a linear multivariate discriminant function of the sedimentary lithogenous phase; s5, determining the distribution characteristics of the sedimentary diagenesis facies on the single well; s6, rock physical elastic parameters of various wells are calculated; step S7, screening sensitive elastic parameters capable of distinguishing favorable sedimentary diagenesis phases and secondary favorable sedimentary diagenesis phases; and S8, determining the spatial distribution range of the favorable sedimentary lithogenous phase and the secondary favorable sedimentary lithogenous phase. And a foundation is laid for application of sedimentary diagenesis phase distribution characteristics in oil-gas exploration.

The invention discloses a phase control prediction method for a tight sandstone breaking joint body based on pre-stack and post-stack combined constraint, and relates to the technical field of geophysical exploration. According to the method, delamination processing is carried out on the post-stack data, multi-attribute collaborative analysis is utilized, and the macroscopic boundary of the fracture zone is accurately described to serve as the geological constraint; under the boundary constraint, advantage features of multiple pre-stack fracture prediction results are intelligently fused through the fuzzy competitive neural network, full-scale three-dimensional representation of a fracture system is achieved, the accuracy, reliability and geological consistency of fracture prediction are improved, and a more accurate and reliable decision basis is provided for oil-gas exploration and development of complex reservoirs.

The invention relates to the technical field of strata facies type identification, in particular to a method and device for rapidly identifying shale strata facies, and the method comprises the following steps: obtaining a to-be-detected strata-containing shale sample; the method comprises the following steps: scanning a to-be-detected shale sample containing the strata by using a portable handheld X-ray fluorescence spectrometer, constructing a measuring point position, and measuring elements in the sample point by point at the measuring point position to obtain the mass percent content of the elements; performing contrast microscopic analysis, selecting corresponding part of point positions at the element measuring point positions to prepare rock slices, and identifying the exact lamina phase type of the rock slices under a microscope; according to the method, the element content in the to-be-detected shale sample containing the lamina is measured through the portable handheld X-ray fluorescence spectrophotometer, the lamina phase type is judged and identified through the element content, identification of a single lamina can be completed within one minute, identification of the lamina phase type can be rapidly completed in a field environment in a lossless and low-cost mode, and the identification accuracy is high. And the identification efficiency of the lamina phase type is improved.

The application discloses a fine-grained sedimentary rock facies identification method based on deep learning, relates to the technical field of deep learning and sedimentary rock facies identification, and comprises the following steps: collecting facies curve data and microstructure image data and screening characteristic parameters, generating a standardized multi-modal feature set through a special analysis engine; calling a specific model to perform hierarchical feature extraction on the microstructure image to obtain a deep microstructure feature vector; inputting the two types of features into a special network to output a preliminary identification result through cross-modal attention weight distribution; and adopting a specific algorithm to perform inversion correction and dynamic adjustment on the preliminary result, combining feedback information to construct a facies classification system to complete accurate division. Through multi-source feature deep fusion, cross-modal correlation enhancement and multi-link collaborative optimization, the application realizes efficient and accurate identification of fine-grained sedimentary rock facies, adapts to complex lithological characteristics, and provides support for technical application in related fields.

The present application relates to the geological exploration and oil and gas exploration technical field, specifically relates to a kind of based on geology-geophysical analysis's beach facies dolomite distribution prediction method.The present application first obtains the vertical development characteristics of dolomite in target interval of single well in study area, then determines the vertical seismic reflection characteristics of dolomite, carries out forward modeling on the basis of the vertical seismic reflection characteristics of single well, obtains the lateral seismic reflection characteristics of single well, then different lithology is decomposed by waveform decomposition technology, finally, by comparing waveform component and the vertical development favorable facies zone single well geology and seismic reflection characteristics, the distribution of dolomite is determined.The identification method provided by the present application is not only simple to operate, and in the distribution of dolomite reservoir which is difficult to accurately identify under conventional seismic data, the distribution of dolomite reservoir of different types, different thicknesses and different development positions can be quickly identified, which provides reliable basis for the exploration and development of beach facies dolomite gas reservoir.

The invention discloses a high-precision recovery marine facies compact limestone sedimentary environment and oil-gas dessert area prediction method. The method comprises the steps that S1, an argillaceous limestone phase, an argillaceous limestone phase, a mud-powder crystal limestone phase and a paste limestone phase are divided through X-ray diffraction and slice identification; s2, utilizing a chemical weathering index CIA, a Sr / Ca salinity index and delta 13Corg organic carbon isotope to synergistically recover paleo-climate and paleo-hydrological conditions; s3, combining total organic carbon TOC, organic matter maturity Ro, terrestrial input Al and Ti content and nanopore development degree, and establishing an organic matter-rich high-quality lithofacies evaluation standard; and S4, according to an evaluation standard, well drilling, well logging and seismic data are fused to predict the oil and gas sweet spot area. Through the four steps of lithofacies division, paleoenvironment recovery, evaluation standard establishment and dessert area prediction, high-precision recovery of the marine facies compact limestone sedimentary environment is realized, the dessert area prediction success rate is improved to 78%, and efficient technical support is provided for oil-gas exploration.

The invention discloses a logging rock facies clustering method, system and device, a medium and a program product, and relates to the field of geological rock facies clustering, the method comprises the following steps: obtaining a sampling sequence formed by a plurality of sampling segments of each well, each sampling segment comprising a plurality of logging channel items; carrying out image conversion on the logging channel item of each sampling segment by utilizing a Grubm angle field function to obtain a three-dimensional tensor image of each sampling segment; extracting a first depth feature of the three-dimensional tensor image of each sampling segment, and performing linear transformation on the first depth feature according to a preset feature mapping vector to obtain a second depth feature of each sampling segment; calculating a cosine similarity between any two sampling segments according to the second depth feature, constructing a similarity distance matrix between the two sampling segments according to the cosine similarity, and aggregating the similarity distance matrix to obtain a clustering tree; and clustering the logging curve of the to-be-logged well based on the clustering tree to obtain a clustering result of the logging lithofacies.

The application discloses a river facies sand body connectivity quantitative prediction method based on a characteristic factor master control, and belongs to the field of oil and gas field exploration and development and geophysical technology. The method is based on the data of drilled wells in a target area, carries out sand body connectivity analysis, and screens out typical sand bodies with reliable connectivity. Then, the horizontal gradient and waveform change index attributes of the screened sand bodies are extracted to construct a master control characteristic factor. Meanwhile, a plurality of seismic attributes reflecting sand body connectivity are extracted, and high sensitivity attributes are reserved as auxiliary characteristic factors through optimization processing. Finally, based on a depth forest algorithm, a mapping model between a multi-factor combination and sand body connectivity is established through machine learning, and the corresponding factor combination of a to-be-predicted sand body is input into the model, so that the quantitative determination of the connectivity can be realized. The application has high accuracy and timeliness in processing the river facies sand body connectivity prediction problem, and provides a new idea and method for the sand body connectivity research under similar complex geological conditions.

The present application belongs to the technical field of oil and gas exploration, and particularly relates to a kind of exploration method of restricted tidal flat facies carbonate rock gas reservoir. Based on rock, logging data, seismic data, experimental test analysis data, through microfabric analysis, macro and micro combination approach, through rock fabric and mineral identification, restricted tidal flat facies rock development characteristics and regional scope are identified and defined; wherein the rock samples include pore development samples and samples with lithology of dark mudstone and argillaceous carbonate rock; frequency spectrum analysis method, weighted average method, organic matter mass balance method and coherent technology method are used to construct high-frequency sequence lithology-electricity interpretation model and multi-scale through-source fault transport pattern; thus, restricted tidal flat facies carbonate rock gas reservoir accumulation mode is obtained to explore restricted tidal flat facies carbonate rock gas reservoir. The present application innovatively explores restricted tidal flat facies carbonate rock gas reservoir, and solves the technical problems of identification and fine description of this type of gas reservoir.

The invention provides a continental facies shale interlayer bedding seam activation capability evaluation method and device and a medium, and belongs to the technical field of oil and gas reservoir development. The method comprises the following steps: establishing a continental facies shale three-dimensional cohesion unit method multi-cluster fracturing model, performing multi-factor simulation analysis by using the model to obtain fracturing crack propagation forms under different factors and activation conditions of a shale interlayer bedding interface, and drawing an interlayer bedding interface activation chart. According to the method, the three-dimensional cohesion unit method multi-cluster fracturing model is adopted to describe the three-dimensional multi-cluster fracturing fracture form of the continental facies shale, the fracture expansion form and the bedding interface opening condition can be accurately evaluated, and the model can consider the mutual disturbance effect among the multi-cluster fractures and the stress interference effect of the adjacent bedding interfaces; the activation condition of each bedding interface under the conditions of different clusters, crack initiation positions, displacements and liquid viscosities is obtained through variable analysis, and help is provided for the fracturing construction process, segment cluster division optimization and construction parameter optimization.