501 results about "Arenite" patented technology

The invention discloses a method for determining the plugging thickness of a complex lithologic layer based on simplified lithologic combination, and the method comprises the steps: determining the vertical superposition relation of a silty rock layer and a shale layer and the total thickness of the silty rock layer and the shale layer according to the lithologic longitudinal distribution characteristics of an overlying stratum; integrally forming and preparing a roof rock sample by combining the properties of siltstone and shale; arranging a plurality of groups of temperature sensors, pressure sensors and strain sensors on the side surface of the rock sample at set intervals; heating the rock sample until the bottom temperature is the set temperature, pressurizing until the bottom pressure is the set pressure, applying stress to the bottom of the rock sample step by step from small to large until the set stress, and stabilizing at the temperature, the pressure and the stress until the measured value of the sensor is stable; determining the lower limit of the roof plugging thickness according to the measured value of each sensor and the up-and-down superposition relationship; and similarly, determining the bottom plate plugging thickness lower limit. According to the method, through simplified lithology and combined simulation of a temperature field, a pressure field and a stress field, the lower limit of the plugging thickness of the shale reservoir complex lithology roof and floor is reasonably quantified.

The invention discloses a method for determining the plugging thickness of a complex lithologic layer based on temperature-pressure field simulation, and the method comprises the steps: determining the vertical superposition relation of a silty rock layer and a shale layer and the total thickness of the silty rock layer and the shale layer according to the lithologic longitudinal distribution characteristics of an overlying stratum in a set range; respectively obtaining formulas for preparing siltstone and shale through experimental fitting; integrally forming and preparing a roof rock sample; arranging multiple groups of temperature sensors and pressure sensors on the side surface of the rock sample at set intervals; heating the rock sample until the bottom temperature is the set temperature, pressurizing the rock sample until the bottom pressure is the set pressure, and stabilizing at the temperature and the pressure until the measured value of the sensor is stable; determining the lower limit of the roof plugging thickness according to the measured value of each sensor and the up-and-down superposition relationship; and similarly, determining the bottom plate plugging thickness lower limit. According to the method, the lower limit of the plugging thickness of the shale reservoir complex lithology top and bottom plates can be reasonably quantified through simplified lithology and joint simulation of a temperature field and a pressure field.

The invention discloses a siltstone adjacent layer plugging thickness lower limit determination method of a shale reservoir, which comprises the following steps: judging that the fracture pressure of the shale reservoir is smaller than the minimum starting pressure of an overlying siltstone rock layer, and executing the following steps: arranging heating, pressurizing and stress devices and temperature, pressure and strain sensors on the bottom surface of a roof rock sample; multiple groups of pressure and strain sensors are arranged on the side surface at set intervals; a heating device is used for heating the bottom of a rock sample to a set temperature, a pressurizing device is used for pressurizing the bottom to a first set pressure, a stress device is used for applying stress to the bottom of the rock sample from small to large step by step to a first set stress, and the stress is stable until measured values of all sensors are stable; determining the lowest position where the rock sample pressure is not higher than the second set pressure and the strain is not higher than the set strain according to the measured value of the sensor; determining a roof plugging thickness lower limit; and similarly, determining the bottom plate plugging thickness lower limit. The method can reasonably quantify the lower limit of the top and bottom plate plugging thickness through temperature, pressure and stress field joint simulation.

The invention discloses a method for analyzing a sedimentary basin object source based on the detrital zircon age, and belongs to the field of analysis and detection, and the method comprises the following steps: S1, uniformly sampling in a known well and a potential object source area of a target layer to obtain a rock sample; s2, slicing the obtained rock sample to obtain a plurality of common slice samples and casting body slice samples, then performing component identification on slices, and analyzing identification results; s3, performing statistics on sandstone debris components of the Benxi group sample in the research area, and drawing a lithologic triangular diagram; s4, drawing a Qt-F-L diagram according to the debris component data of the research area; s5, representative samples in the research area are selected for heavy mineral analysis; s6, selecting representative samples in the research area, and measuring major elements and rare earth elements in the representative samples to analyze the material source supply condition of the research area; s7, performing U-Pb chronological characteristic analysis on the fragment zircon of the sample; and S8, performing U-Pb dating analysis on the fragment zircon of the sample.

The invention belongs to the petroleum and natural gas exploitation industry, and particularly relates to a loose sandstone reservoir fracturing filling double-particle-size proppant combination parameter optimization design method, which performs optimization design on specific parameters of the proppant such as filling particle size, filling seam length proportion, filling sequence and the like according to reservoir and oil well conditions and a corresponding double-particle-size combination mode. And finally, effective sand blocking is achieved, meanwhile, invasion blocking and permeability damage of stratum sand to a crack filling layer are reduced, the crack flow resistance is reduced, the comprehensive flow conductivity is improved, and the comprehensive effects of releasing the oil and gas well productivity are achieved.

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 determining the shale content of tight sandstone, and relates to the technical field of exploration and research of tight rock oil and gas reservoirs. The method comprises the following steps: identifying a rock slice identification photo by using a computer image identification method, obtaining the area percentage of debris particles with the diameter greater than a set threshold value in the slice identification photo, and then calculating the area percentage of argillaceous particles in the slice identification photo; according to the area percentage of the argillaceous particles and the corresponding times of the polarizing microscope, displaying the argillaceous particles in a rectangular coordinate system in a scatter mode; fitting all scatter points by using a nonlinear least square method, and establishing a shale content volume percentage change relation curve under different objective lens multiples of the polarizing microscope; and solving the curvilinear equation, and calculating the shale content of the sample by using the curvilinear equation. According to the method, the error caused by the fact that the shale content is calculated by an eye estimation method singly through a slice identifier is avoided, and the analysis result is more consistent with the real content of the sample, so that the accuracy of the shale content determination by an image method is greatly improved.

The invention belongs to the technical field of oil and gas reservoir evaluation, development and research, and discloses a compact sandstone permeability calculation method based on a saturated nuclear magnetic resonance experiment, which comprises the following steps: carrying out a permeability determination experiment on a compact sandstone sample to obtain a sample permeability value, and recording the sample permeability value as KEm; carrying out a saturated nuclear magnetic resonance experiment on the compact sandstone sample to obtain a nuclear magnetic resonance T2 spectrum curve; logarithms of the nuclear magnetic resonance T2 spectrum and the porosity component # imgabs0 # are taken, a # imgabs1 # intersection curve is constructed, and inflection points of the curve are marked as T2-1 and T2-2 respectively; taking T2-1 and T2-2 as independent variables and KEm as a dependent variable, and establishing a compact sandstone permeability calculation model based on a saturated nuclear magnetic resonance experiment; recording a permeability value calculated by the permeability calculation model as KCal, establishing a KCal-KEm linear relation, and judging the effectiveness of the model according to the correlation coefficient of the KCal and the KEm. According to the method, accurate calculation of the permeability of the tight sandstone reservoir can be realized only by carrying out a saturated nuclear magnetic resonance experiment, and the method has the advantages of being economical, simple, efficient and high in practicability.

The invention discloses a method for determining the plugging thickness of a complex lithologic layer based on temperature-stress field simulation, and the method comprises the steps: determining the vertical superposition relation of a silty rock layer and a shale layer and the total thickness of the silty rock layer and the shale layer according to the lithologic longitudinal distribution characteristics of an overlying stratum in a set range; respectively obtaining formulas for preparing siltstone and shale through experimental fitting; integrally forming and preparing a roof rock sample; arranging multiple groups of temperature sensors and strain sensors on the side surface of the rock sample at set intervals; heating the rock sample until the bottom temperature is the set temperature, applying stress to the bottom of the rock sample from small to large step by step until the set stress, and stabilizing at the temperature and the stress until the measured value of the sensor is stable; determining the lower limit of the roof plugging thickness according to the measured value of each sensor and the up-and-down superposition relationship; and similarly, determining the bottom plate plugging thickness lower limit. According to the method, the lower limit of the plugging thickness of the shale reservoir complex lithology top and bottom plates can be reasonably quantified through simplified lithology and joint simulation of a temperature field and a stress field.

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 invention belongs to the technical field of CO2 plume monitoring, and discloses a method and a system for monitoring sensitive attribute parameters through CO2 oil displacement time-lapse earthquake. The method comprises the following steps: selecting a sandstone reservoir with high porosity and high permeability as a target layer; performing rock physical modeling based on the selected sandstone reservoir, and enabling the rock physical modeling to be equivalent to a rock matrix, a rock skeleton, a pore filler and saturated rock; on the basis of the obtained rock physical modeling, CO2 of different concentrations is injected into the reservoir, and the corresponding speed and density value are calculated through the corrected Batzle-Wang formula; and calculating the AVO response by adopting a Shuey formula after calculating the corresponding speed and density values. According to the method, the influence of CO2 injection on the elastic property of the saturated reservoir rock under the in-situ condition is analyzed, and the accuracy of CO2 plume monitoring by using an earthquake method is improved.

The invention provides a test device and method for simulating seepage, heat transfer, chemistry and stress of high-level radioactive waste disposal, the test device comprises a test box body, a rock-soil body model is arranged in the test box body, the rock-soil body model is composed of sandstone and bentonite, and a heat source is arranged in the middle of the bentonite; a fracture network is arranged in the rock-soil body model, a thermometer, a water pressure gauge and a strain gauge are placed in the fracture network and are in signal connection with a data acquisition instrument, and the data acquisition instrument is in signal connection with a data processing computer; and the test box body is also connected with a fluid supply system. Through repeated model tests, quantitative and qualitative analysis can be carried out on the influence of heat source temperature, different-configuration fracture water seepage paths, fracture water seepage speeds, fracture water chemical properties and inter-fracture water seepage interaction on a rock-soil body model temperature field, a water pressure field and a displacement field; the method has important significance for improving safe disposal of high-level radioactive waste, and is economical and practical.

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 relates to the field of geophysical pre-stack seismic inversion, and provides a compact sandstone reservoir physical property parameter inversion method and system. The compact sandstone reservoir physical property parameter inversion method comprises the steps that a rock physical model considering the rock consolidation degree and the pore structure is established, and consolidation parameters and pore structure parameters are calculated by combining logging data with the rock physical model; fitting the consolidation parameters and the pore structure parameters with the porosity and the shale content in the logging data to obtain a fitting relational expression; the rock physical model is substituted into an Aki-Richard reflection coefficient equation, and an objective function is constructed under a Bayesian framework; and under the constraint of the fitting relational expression, optimizing the target function by adopting a method of alternately updating the reservoir physical property parameters, the consolidation parameters and the pore structure parameters to obtain the reservoir physical property parameters. According to the invention, accurate prediction of the reservoir can be realized.

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 relates to the field of oil and gas development, in particular to a sandstone reservoir fracturing performance evaluation method which comprises the following steps: step 1, determining a plurality of fracturing performance evaluation indexes of a sandstone reservoir; 2, analyzing the influence rule of each factor on the fracture form; 3, obtaining a weight coefficient of the fracturing performance evaluation index; 4, defining a sandstone fracturing index, and determining a comprehensive fracturing coefficient of the sandstone reservoir; and 5, calculating a fracturing index and guiding fracturing well selection and layer selection. According to the method, a plurality of fracturing performance evaluation indexes of the sandstone reservoir are determined by utilizing a rock broken sample of the sandstone reservoir, different fracture forms are obtained by changing parameters such as rock elasticity modulus, fracture energy and minimum horizontal ground stress, and the fracturing performance of the sandstone reservoir is evaluated through micro-earthquake and volume fracturing data regression of a fractured well. The weight coefficients of the multiple fracturing performance evaluation indexes of the compact sandstone reservoir are obtained, so that the brittle interlayer is accurately judged, and the position of the fracturing perforation cluster is optimized conveniently.

The invention discloses a method for dividing a weathering crust structure, which comprises the following steps: collecting data, carrying out regional stratigraphic development characteristic analysis, and selecting a standard well in a research region; selecting a sampling sand body in the target interval according to the logging information of the standard well, and calculating the average acoustic velocity of the sampling sand body; analyzing the average sound wave velocity of the sampled sand bodies of the standard well, and determining the average sound wave velocity of the unweathered sandstone of each group of sand bodies in the target interval of the research area as the sound wave velocity value of the unweathered sandstone; a typical well is selected, the stratum development condition of the typical well is analyzed, and the numerical value of the thick-layer sand body sound wave velocity is determined; calculating the wave velocity ratio of the thick sand body of the typical well in the target interval based on the value of the sound wave velocity of the thick sand body of the typical well and the sound wave velocity value of the unweathered sandstone; performing rock core sampling on the typical well, determining the weathering degree of the rock through experimental analysis, and establishing a standard for dividing the weathering degree and the weathering structure in cooperation with a wave velocity ratio. The method is rapid, accurate and high in operability.

The invention relates to the technical field of rock physical modeling, and provides a turbidite sandstone reservoir earthquake rock physical modeling method and device. The method comprises the following steps: acquiring target turbidite sandstone reservoir information; determining a target rock matrix according to the target turbidite sandstone reservoir information; establishing a dry rock skeleton model by using the average coordination number and the critical porosity of the sandy mineral particles corresponding to the target turbidite sandstone reservoir; and establishing a fluid saturated rock model according to the dry rock skeleton model and a target rock matrix. According to the embodiment of the invention, the average coordination number and the critical porosity of the sandy mineral particles are comprehensively considered, so that the seismic rock physical modeling precision of the turbidite sandstone reservoir can be improved.

The hydraulic fracturing interval division method provided by the embodiment of the invention comprises the following steps: collecting compact thick sandstone stratum cycle and reservoir physical property parameter characteristics and rock mechanical property and parameter characteristics, carrying out normalization processing on physical property parameters, establishing a physical property parameter set, and defining physical property similarity coefficients; based on the processed physical property parameter characteristics, the reservoir is preliminarily divided, and geologic interval division is completed; according to rock mechanics parameters, the number of layers divided by the geological layers is combined, and fine division of engineering layers of the reservoir is determined; establishing a separate layer fracturing crack propagation simulation model according to the number of layers divided by the engineering layer sections, and establishing a hydraulic fracturing crack propagation criterion parameter chart; and determining a final interval division result according to the hydraulic fracturing crack propagation criterion chart. In the embodiment of the invention, the thick compact sandstone reservoir is fully and efficiently transformed, meanwhile, the drilling and fracturing construction cost is reduced, and the oil and gas field recovery ratio and the economic benefit are improved to the maximum extent.

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.