396 results about "Arenite" patented technology

The invention discloses a method for predicting a favorable area of a thin-layer stacked sand body, and relates to the technical field of exploration and development of oil and gas reservoirs, and the method comprises the steps: generating a synthetic seismic record through well-seismic combination by using interval transit time and a density curve, aligning the synthetic seismic record with an actual seismic record, and building a three-dimensional frame model of a target layer of a research area; performing abnormal value elimination and standardization processing on the logging curve, making a statistical histogram, comparing peak separation degrees of sandstone and mudstone, and selecting the most sensitive curve to distinguish the sandstone and mudstone; and realizing well-side seismic trace waveform dynamic clustering analysis through singular value decomposition, and determining the number of effective samples. Based on the result of waveform indication simulation, the method is combined with the optimized seismic attribute to predict the thin-layer stacked sand body together, a systematic method is provided, the multiplicity of solutions of predicting the thin-layer stacked favorable sand body through the seismic attribute and the uncertainty of depicting the sand body by the sedimentary facies in the area with few wells can be reduced, and the prediction accuracy of the thin-layer stacked favorable sand body is improved. Therefore, the precision and reliability of thin-layer stacked sand body prediction are improved.

The invention discloses a portable sedimentary rock classification system and method based on deep learning, and relates to the technical field of rock identification and geological survey. The system comprises a portable microscopic image acquisition module, a cloud deep learning model and a mobile terminal module. A user shoots macroscopic or microscopic images of sedimentary rocks through a mobile phone, the macroscopic or microscopic images are uploaded to a cloud end and then subjected to feature extraction and classification through the optimized ResNet50 model, and a classification result is fed back to a user end in real time. The innovation points comprise: (1) adopting a macroscopic and microscopic data set training model to significantly improve the classification precision; (2) designing a portable microscopic module to realize rapid acquisition of microscopic images; (3) mobile terminal identification service; and (4) the ResNet50 model based on residual network optimization supports high-precision fine-grained classification (sandstone, conglomerate, siltstone and clay rock). Experiments show that the system classification accuracy reaches 99% or above, and compared with a traditional laboratory method, the efficiency is greatly improved. The method can be widely applied to geological exploration, teaching and scientific research and science popularization scenes.

The invention relates to the technical field of rock core fracture segmentation, in particular to an intelligent segmentation model and system for natural fractures of a tight sandstone rock core, and the model comprises a feature extraction unit, a feature fusion unit and a segmentation unit. The feature extraction unit comprises a convolution module, a C2f module and an SPPF module; the feature fusion unit comprises a convolution module, a splicing module, a CARAFE module and an improved Neck network structure BiFPN; the dividing unit comprises a dividing head module. According to the method, the structure of an up-sampling module and a Neck network of a neck network (Neck) of an original YOLOv8m network is improved, a natural fracture segmentation network FracNet suitable for the tight sandstone core is formed, and the recognition precision and efficiency of the natural fracture of the tight sandstone core can be effectively improved.

The invention discloses a method for selecting a post-mining grouting position for thick-layer roof sandstone water disasters. The method comprises the following steps: (1) finely probing a geologic body of a to-be-grouted area; (2) representing the development degree of the native fracture and the water inflow based on a water inflow observation result in the working face pushing and mining process in combination with the development degree of the native fracture, and evaluating the development condition of the water guide channel of the working face; (3) predicting the development height of the water flowing fractured zone; (4) selecting a grouting layer position; and (5) selecting a grouting position. The method disclosed by the invention has the following beneficial effects: 1, fine exploration work is carried out, comprehensive and accurate cognition of geological conditions is realized, and a foundation is built for subsequent work; 2, the grouting layer position and the plane position are selected scientifically and reasonably, blind selection is effectively avoided, and the water control and roof reinforcement effects are guaranteed; errors and waste are reduced, and construction efficiency and quality are improved.

The invention provides a tight sandstone gas reservoir formation water division method based on mercury intrusion and online nuclear magnetic resonance, and relates to the field of gas reservoir formation water production, and the method specifically comprises the following steps: obtaining a tight sandstone core standard rock sample; cutting the rock core into two sections, and performing a high-pressure mercury injection experiment on the first section of the rock core; and scanning the nuclear magnetic resonance signal T2 spectrum curve of the rock core in the completely saturated water state and the area of the nuclear magnetic resonance T2 spectrum curve. And carrying out gas drive and nuclear magnetic scanning experiments. And sequentially increasing the displacement pressure differences to obtain a nuclear magnetic resonance correction curve under different displacement pressure differences. And drawing a water saturation and displacement pressure difference relation curve, and defining the critical pressure difference of different types of formation water production according to the curve form and the slope change rule. And processing the data to obtain the formation water production rule of the tight sandstone gas reservoir in different states. According to the technical scheme, the problem that in the prior art, the critical output pressure difference and the dynamic output rule of various types of formation water in different pore diameter ranges cannot be quantitatively represented is solved.

The invention discloses a sandstone damage simulation experiment device and method based on a seepage-crystallization coupling effect, and belongs to the technical field of mechanical property testing of geotechnical materials. Aiming at the limitation that the seepage-crystallization coupling effect of sandstone in a complex geological environment cannot be effectively simulated in the prior art, the experimental device is designed. According to the device, through the design of a single opening in the bottom, a sample is axially fixed through an O-shaped ring sleeve, a seepage boundary is formed, after a solution with a preset concentration is injected, the seepage rate of the solution is controlled through pressurization of an air compressor, evaporative crystallization is accelerated in combination with directional heating and air supply at the bottom, and dynamic crystallization process simulation of salt in sandstone pores is achieved. The sandstone damage simulation method for realizing solution crystallization through controllable seepage is provided, and a scientific basis is provided for evaluating the durability of sandstone engineering. Through integrated design, precise control and dynamic observation, the experimental precision is remarkably improved, the application range is widened, and the device has important significance in promoting the development of sandstone damage mechanism research in the field of geotechnical engineering.

The present invention provides a geophysical identification method for mid-deep undercompacted low-velocity mudstone. By statistically analyzing data, representative P-wave velocity, S-wave velocity, and density of low-velocity mudstone and gas-bearing sandstone in well logging data are obtained. Combining geological information, a theoretical model of the superimposed relationship between low-velocity mudstone and gas-bearing sandstone is designed, and convolution forward modeling and prestack forward modeling are carried out on it. The post-stack and prestack seismic attributes of the model are calculated respectively. Then, sensitive attributes are optimized from these attributes, and the obtained sensitive attributes are used as learning samples, and the superimposed relationship is identified by probability self-organizing neural network clustering. The present invention adds prestack attributes to the optimization of sensitive attributes, making the fuzzy self-organizing neural network more accurate in identifying the superimposed relationship between gas-bearing sandstone and low-velocity mudstone, effectively distinguishing low-velocity mudstone from gas-bearing sandstone, and providing support for subsequent effective reservoir prediction.

The invention provides a tight sandstone reservoir horizontal well three-dimensional comprehensive compressibility evaluation method and device, and belongs to the technical field of oil-gas exploration. The method comprises the following steps: performing three-dimensional modeling on geological attributes around a target horizontal well, wherein the geological attributes comprise lithology, natural fractures and oil-gas possibility; carrying out geological attribute assignment; fracturing crack propagation simulation is conducted on the penetrating interval of the target horizontal well trajectory; according to different fracture height sweep degrees of fractured fractures, establishing a mapping coefficient, and according to the mapping coefficient, mapping a geological attribute assignment result to the horizontal well to obtain a geological sweet spot index around the horizontal well; and obtaining a comprehensive compressibility evaluation result according to the evaluation parameters including the geological sweet spot indexes around the well. According to the method, lithology, natural fractures and oil-gas possibility in geological dessert attributes around a well are comprehensively considered and mapped into geological dessert indexes around the well, and then the geological dessert indexes around the well are combined with other geological, engineering and technological parameters, so that compressibility evaluation of the compact sandstone reservoir is realized.

The invention belongs to the technical field of oil-gas exploration and development, and particularly relates to a method and a device for calculating physical properties of gypsum sandstone and a storage medium, the method comprises the following steps: S1, acquiring logging data of a target well section, establishing a first model of the target well section, and calculating to obtain porosity # imgabs0 #; if so, executing the step S3; if not, the permeability of the target well section is calculated, and the porosity # imgabs1 # and the permeability are determined as the porosity and the permeability of the target well section; s3, block gypsum in the first model is removed, a second model of the target well section is established, and the porosity and the permeability are calculated; and S4, the permeability K of the target well section is calculated, and the porosity # imgabs2 # and the permeability K serve as the porosity and the permeability of the target well section. According to the method, physical property calculation of the lump sandstone is realized, the accuracy of physical property calculation of the lump pasty sandstone is improved, and an important technical support is provided for later well completion and oil reservoir modeling.

The invention provides a sandstone-type uranium deposit sedimentary facies identification method, system and device and a medium, and belongs to the technical field of sedimentary facies identification, and the method comprises the steps: obtaining sandstone-type uranium deposit sedimentary facies multi-source data; time-frequency domain feature data, texture feature and waveform feature data and element ratio feature and statistical feature data related to sedimentary facies in the sedimentary facies multi-source data are extracted; time sequence features, three-dimensional structure features and metallogenic environment features are extracted from the feature data and weighted fusion is carried out to obtain the sedimentary facies category recognition probability. Multi-dimensional information complementation is realized by combining logging, earthquake and geochemical data, covering vertical lithology change, three-dimensional sand body distribution and a sedimentary facies state in a redox environment scene, and the focusing capability and the recognition precision of the model are effectively improved.

The invention relates to the field of petroleum and natural gas engineering, in particular to a method for testing the oil and gas storage capacity of a tight sandstone reservoir in the exploration and development process. A tight sandstone reservoir oil and gas reservoir capacity testing method comprises the following steps: acquiring a pressure-time curve of a tight sandstone target reservoir section and an upper cover rock sample thereof; constructing a pressure drop standard function; respectively fitting the pressure-time curve of the target reservoir section rock sample and the pressure-time curve of the cover rock sample with a pressure drop standard function to obtain a target reservoir section pressure drop function and a cover pressure drop function; and calculating a reservoir physical property similarity coefficient according to the pressure drop function of the target reservoir section, calculating a cap layer physical property deviation coefficient according to the cap layer pressure drop function, taking an arithmetic square root of a product of the reservoir physical property similarity coefficient and the cap layer physical property deviation coefficient as an oil and gas reservoir index, and evaluating the reservoir capacity according to the oil and gas reservoir index. The method has popularization and application values.

The invention provides a stratigraphic contrast method and system for a heterogeneous multilayer sandstone oil field and computer equipment, and belongs to the field of oil-gas field development. The stratigraphic contrast method for the heterogeneous multi-layer sandstone oil field comprises the following steps: dividing different levels of standard layer boundary lines for each development well in a target area; determining the sedimentary environment of a layer section between two adjacent standard layer boundary lines of each development well according to preset different sedimentary environment stratum development characteristic evaluation standards; dividing a boundary line of a continuous deposition unit of a layer section according to a deposition environment of the layer section between two adjacent standard layer boundary lines of each development well to obtain a preliminary stratum boundary line division result; and establishing a three-dimensional space model in the stratum section based on the preliminary stratum boundary division result, and correcting the stratum boundary division result through the three-dimensional space model in the stratum section to obtain an optimal stratum boundary division result.

The invention discloses an ocean deepwater weakly cemented sandstone saturated water nuclear magnetic T2 spectrum correction method, which comprises the following steps: 1, making a standard rock sample, and drying the rock sample until the quality is kept stable; 2, saturating the dried rock sample to a completely saturated state by using a turbid liquid, and carrying out nuclear magnetic T2 spectrum measurement to obtain a nuclear magnetic T2 spectrum of the weakly cemented rock sample under the condition that pores contain tiny solid impurities; 3, after displacing and drying the rock sample in the previous step, carrying out saturated water treatment by utilizing pure water, and then carrying out nuclear magnetic T2 spectrum measurement to obtain a nuclear magnetic T2 spectrum of the rock sample in a state that the pores contain the pure water; 4, constructing the nuclear magnetic T2 spectrums in the two states into a data set, and inputting the data set into a deep neural network model for training; and 5, correcting the nuclear magnetic T2 spectrum under the condition that the pores contain the tiny solid impurities by using the trained deep neural network model. According to the method, the nuclear magnetic T2 spectrum is corrected by using the deep neural network model, and the problem of signal attenuation distortion caused by impurity interference is effectively solved.

The invention discloses a low-permeability sandstone water locking-water sensitivity synergistic plug removal deep acidizing treatment method which is suitable for a low-permeability sandstone reservoir in an offshore high-temperature and high-pressure environment (120 DEG C, 40 MPa). According to the method, acidizing fluid is adopted, and the acidizing fluid is prepared from 18%-22% of chelating type composite organic multi-element retarded acid HWCP, 1.5%-2.5% of clay stabilizer HTW, 1.5%-2.5% of waterproof locking agent HAR, 18%-22% of pressure reduction cleanup additive HWDA, 5%-7% of corrosion inhibitor HWCI and the balance filtered seawater. The acidizing fluid is prepared by stirring at normal temperature and normal pressure, and stays for 6-12 hours after being injected into a reservoir. The HWCP slowly dissolves blockages, and the acting distance reaches 11 m; the HTW anti-swelling rate is greater than or equal to 90%, and clay expansion is inhibited; the HAR prevents water blocking; secondary precipitation is reduced through HWDA; and the corrosion rate is controlled to be 15.1108 to 26.1274 g / m < 2 >. H through HWCI. According to the method, the permeability of the reservoir is recovered by 122.09%-627.1%, the yield-increasing multiple ratio is 1.60-2.91, and the high efficiency is verified through 7-well-number field application. The method is simple in process, adapts to the marine environment, and comprehensively solves the problems of water locking, water sensitivity and secondary precipitation.

The invention discloses a method for predicting a high-quality reservoir of deep-buried matrix type tight sandstone. The method comprises the following steps: acquiring production data and reservoir physical property parameters of a target work area; drawing a porosity cumulative frequency and cumulative probability distribution diagram and a permeability cumulative frequency and cumulative probability distribution diagram according to the production data and the reservoir physical property parameters; respectively determining a porosity inflection point, a first permeability inflection point and a second permeability inflection point according to the porosity cumulative frequency and cumulative probability distribution diagram and the permeability cumulative frequency and cumulative probability distribution diagram; selecting a plurality of samples of the target work area, and determining a permeability upper limit point according to the plurality of samples; according to the porosity inflection point, the first permeability inflection point, the second permeability inflection point and the permeability upper limit point, reservoir types are divided, and a high-quality reservoir is determined. The method not only provides scientific basis for tight sandstone gas prediction, but also provides theoretical guidance for exploration and development of tight sandstone gas with similar geological backgrounds, and has important practical value for exploration and development of deep-layer and ultra-deep-layer tight sandstone gas.

The invention belongs to the field of petroleum geology and fluid geochemistry, and discloses a method for limiting opening duration of a natural horizontal hydraulic fracturing tensible fracture in a reservoir. The method comprises the following steps: determining that a horizontal tensional fracture is developed in rock, collecting a rock sample, making a fluid inclusion slice, determining the characteristics of filling blocky crystals in the fracture, combining fluid inclusion lithofacies observation and laser Raman spectroscopy analysis technologies, and selecting a methane-rich fluid inclusion combination as a research object. And carrying out subsequent microscopic temperature measurement analysis and PVT simulation, combining a PVT simulation result with a basin evolution history, and finally obtaining the opening duration of the natural horizontal hydraulic fracturing tensible fracture on the basis of judging the existence of the ultra-quiet rock fluid pressure. The method is low in cost and high in operability, and a certain judgment basis is provided for enrichment and loss of shale gas and tight sandstone gas.

The invention belongs to the field of rock physics research, and relates to a tight sandstone well logging permeability determination method and device, electronic equipment and a computer readable storage medium. Comprising the following steps: acquiring permeability test data and porosity test data of a core sample in a target area; obtaining a relational graph of different porosity test data and density; performing linear fitting to obtain a porosity calculation formula: P =-33.218 D + 88.431; applying the porosity calculation formula to porosity calculation of the target horizon to obtain a porosity curve of the target horizon; obtaining a relational graph of different permeability test data and porosity test data; performing linear fitting to obtain a permeability calculation formula: PER = 0.0148 e < 0.427 > P; and based on the porosity curve, performing permeability calculation by utilizing a permeability calculation formula to obtain a permeability curve. The flow method is simple, the stratum permeability value of the well can be better simulated and calculated, and meanwhile the problems of complexity and multi-parameter and multi-solution of porosity and permeability prediction through a rock physical model are solved.

The invention belongs to the field of rock burst prevention and control coal mining methods, and particularly relates to a roof-cutting pressure-relief coal mining method under the stratum condition of a deeply-buried sandstone group. Comprising the following steps: respectively constructing detection drill holes inside and outside a first mining working face, and checking an interface in a stratum in a hydraulic pressure test mode so as to accurately determine a key layer. On the basis, on the basis of gob-side entry retaining, roof cutting drill holes are creatively constructed in a roof cutting special roadway and a transportation roadway correspondingly, so that roof cutting work is conducted on key layers in a bent sinking zone rock stratum, a water flowing fissure zone and a caving zone rock stratum in a roof; therefore, the suspended roof length of a part of the water flowing fractured zone rock stratum and the caving zone rock stratum is reduced but still reserved, the supporting force needing to be borne by the gob-side entry retaining is reduced, and a sheltering space is provided for the gob-side entry retaining. The bent sinking zone rock stratum is subjected to vertical drilling top cutting, and a top cutting transition area is reserved, so that superposition of fracture of the bent sinking zone rock stratum and fracture of the water flowing fissure zone rock stratum can be reduced, and the stratum pressure needing to be borne by gob-side entry retaining is reduced to the maximum extent.

The invention discloses an attenuation rock physical quantity plate construction method, electronic equipment, a storage medium and a device. The method comprises the following steps: acquiring rock physical parameters of a tight sandstone reservoir rock sample under different confining pressures and water saturation based on a variable fluid rock physical experiment, analyzing the sensitive degree of each rock physical parameter to a fluid based on a fluid indication factor, and further determining a sensitive parameter with high sensitive degree to the fluid, and establishing a dual-dual pore medium model, obtaining a change relationship between each sensitive parameter and the rock reservoir characteristic parameter based on the dual-dual pore medium model, and constructing an attenuation rock physical quantity plate based on each sensitive parameter and the corresponding change relationship. According to the method, the attenuation rock physical quantity plate for introducing attenuation characteristic fluid identification is constructed, the porosity and saturation of the tight sandstone reservoir can be accurately predicted aiming at the condition that the tight sandstone reservoir simultaneously contains a pore structure and fluid heterogeneity, and a theoretical support is provided for fine prediction of the gas-bearing property of the tight sandstone reservoir.

The invention discloses a method for describing remaining oil based on well-seismic combination pre-stack inversion, and belongs to the technical field of inter-well reservoir oil quantity prediction. The pre-stack geostatistical inversion and the pre-stack joint inversion fusing the prior geological information have good consistency in the transverse trend, the inversion result accords with the deposition law macroscopically, the actual drilling data is respected at the well point, and the reservoir deposition characteristics are reflected more objectively and truly; the pre-stack geostatistics inversion effectively fuses logging high-frequency information, the longitudinal recognition capability is greatly improved, and the inversion result can accurately describe the spatial distribution of the oil-containing sand body; according to the actual inversion effect, the cross section transverse comparison shows that the inter-well transition is natural, and the spatial distribution characteristics of the sand body conform to the deposition law; and according to pre-stack inversion and remaining oil research results, well pattern analysis is carried out according to a supplementary well design principle, the sandstone thickness and the oil-water well communication condition in the potential area are evaluated, and well position design is optimized.

The invention provides a volcanic rock matrix-fracture dual-medium type oil reservoir oil layer evaluation method and system, and belongs to the technical field of geological engineering, oil reservoir processes and well logging interpretation. According to the method, a matrix porosity calculation chart is established through core scale logging, crack pores are added into an Archie sandstone conductive model to serve as conductive channels, the crack porosity is deduced, and finally, the matrix pores, the crack pores, the oil saturation and an oil testing result are combined to obtain the conductivity of the Archie sandstone. And the quantitative distinguishing method for the matrix-fractured dual-medium oil and gas reservoir oil layer is formed. According to the method, the gap of simultaneous research of the matrix and the crack is filled, the oil layer recognition precision is improved, the judgment standard is more strict and more reasonable, and the reliability is high.

This application relates to the technical field of rock mechanics and rock physical simulation tests, and discloses a sample preparation method and device for shear-slip tests applicable to fractured tight sandstone. The sample preparation method mainly includes the dissolution and re-casting of the clastic components of tight sandstone. The device includes an embedded design of a compound bourdon tube in the drilled holes of the prepared specimen. The specimen made by using the sample preparation method proposed by the present invention can not only meet the variable comparison study of shear-slip tests on fractured tight sandstone under single variable control, but also maximize the consistency of the mechanical properties of the specimen with those of tight sandstone, ensuring the accuracy of the research results and effectively solving the problem that the two cannot be achieved simultaneously by traditional sample preparation methods. The test device described in the present invention can effectively avoid the unnatural changes in the slit width and slit surface roughness of the shear-slip and dislocation parts at both ends of the specimen in traditional sample preparation, further ensuring the accuracy of the test results.

The invention discloses a tight sandstone gas reservoir horizontal well volume fracturing fracture characteristic parameter obtaining method and device and a storage medium. The method comprises the following steps that S10, the change relation of the pumping pressure, the displacement and the sand ratio along with time is obtained based on a fracturing construction curve; and S20, the effectiveness of fracturing construction is judged. And S30, geological parameters, well completion parameters and construction parameters of a fracturing implementation well are obtained, and a horizontal well fracturing geological model, a stress field model and a wellbore model are established. And S40, fracturing pump injection program parameters are input based on the fracturing construction bulletin. And S50, on the basis of the geological parameters, the well completion parameters and the construction parameters, fracturing crack characteristic parameters are solved. With the adoption of the method, the form and characteristic parameters of the fracturing crack can be obtained after the field fracturing construction is finished, so that a support is provided for evaluating the fracturing yield increasing effect.

The invention discloses a preparation and experiment method of a filled fractured rock sample reflecting moisture migration water-containing conditions, and relates to the technical field of rock mass mechanics experiments, and the preparation and experiment method comprises the following steps: processing a sandstone block material into a cuboid larger than a standard cylindrical sample; the rectangular plate is placed on a drilling machine workbench, the drilling position is marked according to the needed sample position, and a rock core drilling machine is used for preparing a sample; high-pressure water jet equipment is used for cutting a penetrating crack in the middle of the sample, the crack characteristics comprise the inclination angle beta and the length 2a, the crack widths are the same, and control groups of different rock samples are formed; cutting and grinding by using a stone grinding machine to prepare standard cylinder and disc samples; the method comprises the following steps: air-drying and grinding clay taken back from a sampling site, preparing a clay filler according to the natural moisture content of the clay on site, and preparing a clay filling crack sample; the method can provide a basis for understanding a water-rock interaction mechanism and revealing a water-induced related rock mass engineering disaster mechanism.

The invention discloses a multi-scale analysis-based gas-water seepage field simulation method, which specifically comprises the following steps of: based on a digital rock core reconstructed by a CT (Computed Tomography) scanning image of a typical rock sample of a target reservoir, adopting a microcosmic pore network flow simulation technology; the change rule of the stratum seepage capacity in different stratum pressure gradients and water drive processes, the use degree of a pore network and the water drive process in a pore are calculated, and then a correlation chart with the rock permeability and the pressure gradients is established and used for rapid measurement and calculation of the actual reserve use degree and the recovery degree of the water-invaded sandstone gas reservoir. The method starts from a rock microcosmic pore channel, the scale is amplified to a macroscopic oil reservoir during application, the method has the cross-scale characteristic, and the method is used for rapidly measuring, calculating and evaluating the reserve utilization degree and the recovery degree of the actual water-invaded sandstone gas reservoir and is beneficial to rapid development of the gas reservoir engineering scheme design in a mine field.

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

This invention belongs to the fields of rock mechanics, geological engineering, and geophysical exploration technology. Specifically, it discloses a method and system for constructing a mapping relationship between acoustic wave velocity and surrounding rock stress. The method includes: performing uniaxial graded loading on a standard sandstone sample and simultaneously measuring the P-wave velocity and S-wave velocity under each stress level; then fitting a linear mapping relationship between the P-wave / S-wave velocity ratio and the axial stress of the surrounding rock; introducing joint correction coefficients and water content correction coefficients to optimize the linear mapping relationship and constructing an acoustoelastic model; and using the acoustoelastic model and field-measured wave velocity data to invert the stress state of the actual surrounding rock, thus completing the construction of the acoustic wave velocity-surround rock stress mapping relationship. This invention solves the problems of traditional wave velocity-stress relationships, which, when describing the nonlinear response of rocks at different stress stages, are not sensitive enough to subtle stress changes and lack a complete, high-precision, and interference-resistant stress inversion calculation method, making them difficult to directly apply to complex actual engineering environments.

The present application relates to a kind of thin interbed type deposit high-quality reservoir prediction method, comprising: obtaining the geological data, seismic data and well logging data of the region to be analyzed, well seismic combination tracking interpretation oil group top, bottom interface;With the oil group top, bottom interface as constraint, utilize the three-dimensional seismic data acquisition three-dimensional seismic inversion data;With the oil group top, bottom interface as constraint, according to the three-dimensional seismic inversion data and the well logging data are combined, obtain oil group internal relative isochronous sedimentary interface;According to the oil group internal relative isochronous sedimentary interface, based on three-dimensional seismic inversion data, each small layer reservoir plane distribution in oil group is solved;According to the three-dimensional seismic inversion data, based on the information of actual drilling well, sandstone probability body seismic data is solved;Utilize actual drilling well information to construct reservoir classification standard, realize single well reservoir type division;According to the sandstone probability body seismic data, with single well reservoir type as constraint, carry out high-quality reservoir space distribution prediction.

The invention belongs to the technical field of rock particle screening, in particular to a rock particle screening device for loose sandstone artificial core preparation, and provides the following scheme that the rock particle screening device comprises a screening box and two groups of screening plates, and further comprises a separation frame mounted in the middle of the screening box, and the two groups of screening plates are rotationally connected with the side edge of the separation frame through torsional springs; a cavity with an opening in the bottom is formed in the middle of the partition frame, meshes are formed in the two sides of the cavity and located above the sieve plate, a magnetic attraction piece and an electromagnetic block which are matched are arranged below the sieve plate, and the sieve plate swings through changes of magnetic attraction force of the electromagnetic block and the magnetic attraction piece. Rock particles on the sieve plate are alternately impacted and dispersed between the sieve plate and the side edge of the separation frame for screening through movement operation of the sieve plate in a sudden change state, so that the agglomerated rock particles are effectively dispersed, the screening effect is improved, and the screening operation efficiency is improved.

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.