185 results about "Arenite" patented technology

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 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 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.

The invention relates to the technical field of oil and gas reservoir damage evaluation, in particular to a method and device for calculating irreducible water saturation of a tight sandstone reservoir, electronic equipment, a storable medium and a computer program product. The method comprises the following steps: acquiring a pore distribution curve of a compact sandstone sample; based on the pore distribution curve of the compact sandstone sample, determining the capillary bound water content of different pressure differences of the compact sandstone reservoir; carrying out total rock and clay mineral analysis on the compact sandstone sample to obtain the content of the clay bound water in the compact sandstone reservoir; and obtaining the irreducible water saturation of the tight sandstone reservoir based on the capillary irreducible water content and the clay irreducible water content. According to the method, the relationship between the absolute content, the pore distribution, the stress distribution and the interfacial tension of the clay mineral and the irreducible water saturation is established, so that qualitative and quantitative analysis on the irreducible water saturation is quickly and accurately performed.

The invention belongs to the technical field of anti-seepage curtains of red-bed landfills, and discloses an optimal design method for a vertical anti-seepage curtain of an irregular landfill in a red-bed region, which adopts a drilling, geological radar and X-ray diffraction combined technology in the exploration and data acquisition stage to clearly distinguish hydrophilic expansive mudstone and high-permeability sandstone, and the optimal design method for the vertical anti-seepage curtain of the irregular landfill in the red-bed region is provided for the vertical anti-seepage curtain of the irregular landfill in the red-bed region. A space coupling model of the pile body and the red rock stratum is established by means of three-dimensional laser scanning, and the lithologic boundary of the dual seepage system is defined; in the model construction stage, parameter distribution is analyzed through a Markov random field model, regular updating is conducted in combination with a Kalman filtering algorithm, and dynamic changes such as sandstone fracture expansion caused by pile settlement can be adapted; a modified bentonite and nanoscale montmorillonite composite material is used in a sandstone area, construction is conducted through a high-pressure jet grouting technology, the permeability coefficient is set to be that the insertion depth extends to the complete bed rock by 2-2.5 m, and the problem of local leakage caused by the fact that the seepage-proofing design is not matched with the actual conditions of a red layer is solved.

The embodiment of the application relates to the technical field of sandstone type uranium ore exploration, and particularly relates to a method for determining a favorable area of a sandstone type uranium ore, which comprises the following steps: collecting well logging data of an exploration area of the sandstone type uranium ore, and gradually determining argillaceous content, total porosity of the exploration area, sandstone content of a sand and shale mixed matrix, longitudinal wave time difference, transverse wave time difference and density, equivalent elastic modulus of dry rock of the exploration area, and conversion relationship between longitudinal wave velocity and transverse wave velocity of rock under saturated fluid condition and a transverse wave velocity prediction curve; then, longitudinal wave impedance, velocity ratio of longitudinal wave and transverse wave and a density model are established; according to the model, three-dimensional elastic data bodies of impedance, density and shear modulus of longitudinal wave and transverse wave are determined by inversion; and according to the three-dimensional elastic data bodies, the favorable area of the sandstone type uranium ore is determined. The method for determining the favorable area of the sandstone type uranium ore according to the embodiment of the application can effectively improve the prediction accuracy of a favorable area of a sandstone type uranium ore.

The invention discloses a quantitative evaluation method for the transverse plugging performance of a multilayer sandstone oil reservoir fault. The quantitative evaluation method comprises the steps that a layer surface model and a fault model which can reflect a stratum space framework are established; obtaining a three-dimensional lithofacies model; acquiring the contraposition condition of two sand shale reservoirs of the fault; calculating an improved transverse plugging coefficient; and performing quantitative evaluation on the fault plugging property according to data such as an oil field seismic section and tracer test and comprehensive analysis of a numerical simulation method. According to the method, the multi-layer overlapping effect is considered, the influence of the fault displacement on mudstone smearing continuity and lithologic configuration can be considered, the threshold chart of the fault static transverse connectivity is established, verification is conducted in combination with a numerical simulation method, the fault plugging performance prediction precision can be effectively improved, and the fault plugging performance prediction accuracy is improved. And a reliable basis is provided for further development and adjustment of the multi-layer sandstone reservoir.

The invention discloses a tight sandstone reservoir water-containing gas well water block removing agent and a preparation method and application, belongs to the technical field of gas reservoir development, and is characterized in that the water block removing agent comprises the following components in parts by weight: 20-35 parts of an ampholytic surfactant, 0.3-0.5 part of a fluorocarbon surfactant, 5-10 parts of a wetting agent, 5-10 parts of a solvent and 30-45 parts of water. The prepared water block removing agent is easy to biodegrade and low in surface tension and interfacial tension, the wettability of a rock core can be gradually changed from hydrophilic to hydrophobic, the rock wettability is effectively changed, the interfacial tension between fluid and reservoir rock is reduced, the permeability of the rock core is improved, and then the single-well recovery efficiency of a tight sandstone gas reservoir water-containing gas well is improved.

The invention discloses a method and system for predicting the maximum height of an oil column of an upper-generation lower-storage type sandstone reservoir, and the method comprises the steps: building a dynamic critical equilibrium relational expression which takes hydrocarbon expulsion intensity and oil column formation height as unknown quantities and is used for representing an oil column formation condition and a force equilibrium relation according to the basic parameters of a hydrocarbon source rock stratum to be researched; according to pyrolysis experiment parameter data of multiple wells in the hydrocarbon source rock stratum to be researched, hydrocarbon expulsion intensity at different depths is calculated; and substituting the hydrocarbon expulsion intensities at different depths into the dynamic critical equilibrium relational expression so as to obtain the maximum oil column formation height at different depths. According to the method, the reliability and the accuracy of predicting the maximum height of the oil column of the upper-growing lower-storage type sandstone reservoir are improved.

The application discloses a horizontal well geosteering method, comprising the following steps: acquiring basic data of adjacent wells around a to-be-drilled horizontal well; comparing target reservoirs to obtain the numerical values of the top depth and the bottom depth of the target reservoirs of the adjacent wells and the predicted values of the top depth and the bottom depth of the to-be-drilled horizontal well; comparing X-ray element data to predict the sandstone types of the target reservoirs and the reaction characteristics of the X-ray element data; obtaining the reservoir thicknesses of each adjacent well and the to-be-drilled horizontal well, and establishing a target reservoir thickness model; when the to-be-drilled horizontal well is under construction, drilling to a target point, analyzing and judging whether the actual sandstone type of a drilled formation is the predicted sandstone type, analyzing whether the actual sandstone type is consistent with the predicted value, and when the results are all yes, determining that the model is correct, and continuing to perform horizontal well geosteering. The method can timely correct the prediction result of a seismic inversion reservoir, provide a basis for trajectory adjustment of horizontal well construction, improve the drilling rate of the reservoir, and improve the success rate of trajectory adjustment.

The application provides a method and system for determining the permeability of a tight sandstone reservoir. The method comprises: obtaining the porosity and pore throat radius distribution spectrum of the target reservoir; dividing the pore throat radius distribution spectrum of the target reservoir into two parts, i.e., a large-aperture part and a small-aperture part; determining the ratio of the cumulative amplitude of the pore throat radius distribution of the large-aperture part to the cumulative amplitude of the pore throat radius distribution of the small-aperture part based on the pore throat radius distribution spectrum of the large-aperture part and the small-aperture part of the target reservoir; and determining the permeability of the target reservoir based on the ratio and the porosity of the target reservoir. The method can accurately determine the permeability of a reservoir in a tight sandstone reservoir with strong heterogeneity.

The invention belongs to the technical field of petroleum and natural gas exploration and development, and provides a method and a device for analyzing the rock resistivity of glauconite sandstone. Generating a first relation curve and a second relation curve according to the different glauconite content conditions, the rock water saturation of the glauconite sandstone, the rock resistivity of the glauconite sandstone and the rock resistance increase rate of the glauconite sandstone corresponding to the different glauconite content conditions; and analyzing the change trend and the change degree of the rock resistivity and the rock resistance increase rate of the glauconite sandstone to obtain an analysis result. According to the analysis method provided by the embodiment of the invention, quantitative analysis can be carried out on the low-resistivity cause of the glauconite sandstone stratum, and the influence and degree of the change of the content of glauconite, the change of the rock resistivity of the glauconite sandstone and the change of the rock resistance increasing rate can be quantitatively judged.

The application relates to a micro-fracturing sand-prevention filling well completion process. The micro-fracturing sand-prevention filling well completion process comprises the following steps: filling a high-permeability layer with high water content by using a first particle-carrying liquid containing selective proppants; and filling a low-permeability layer with high remaining oil saturation by using a second particle-carrying liquid. The application solves the problem of uneven liquid production profile caused by the prominent interlayer contradiction of loose sandstone reservoirs, can effectively improve the liquid production profile, solve the interlayer contradiction, release the productivity of the production well and improve the effect of water control and oil increase.

The present application belongs to the technical field of oil exploration, and discloses a method for evaluating the development degree of sand-mudstone reservoir-cap assemblage, which specifically comprises the following steps: conducting regional data analysis for a study area, and mastering the core / cuttings data, logging data and oil testing and production testing data of drilled wells, as well as the seismic data and seismic interpretation horizon data of the whole work area; conducting pre-stack deterministic inversion based on Zeoppritz equation to obtain the data body of the ratio of P-wave velocity to S-wave velocity in the work area; extracting the numerical value of the ratio of P-wave velocity to S-wave velocity along the sandstone layer interpreted by the seismic data to obtain the plan view of the sandstone reservoir; extracting the numerical value of the ratio of P-wave velocity to S-wave velocity along the mudstone layer interpreted by the seismic data to obtain the plan view of the mudstone cap rock; quantifying the relative development degree of the reservoir-cap assemblage by a development degree index calculation formula, constructing the plan view of the development degree index of the sand-mudstone reservoir-cap assemblage, and quantitatively dividing the development degree of the reservoir-cap assemblage. The present application can clearly define the development range of high-quality reservoir-cap assemblage, delineate the favorable exploration area, and further guide the well site deployment of exploration wells.

The invention discloses a rock physical forward modeling method applicable to formation pore fluid of carbon dioxide, and relates to the technical field of petroleum and natural gas engineering. The method comprises the steps of firstly obtaining a carbon dioxide physical property constraint condition based on a state equation of carbon dioxide under a reservoir temperature and pressure condition, and then based on the constraint condition and according to logging information of a target well, core analysis and a laboratory test result, carrying out formation evaluation to calculate reservoir parameters. Then, based on reservoir parameters, the sandstone content is obtained through calculation, a rock physical volume model of a target well is constructed, and finally, based on the model, corresponding rock physical forward modeling is conducted according to different carbon dioxide saturations by means of the equivalent medium theory to generate stratum elastic attribute parameters. And the change relation between the corresponding saturation and the stratum elastic attribute parameters is quantitatively represented, so that the CO2 quantitative monitoring precision and reliability can be remarkably improved by comprehensively considering the special physical properties of CO2, the fluid replacement mechanism and the seismic wave propagation characteristics.

The invention discloses a well logging interpretation optimization method and device for a water-containing tight sandstone gas reservoir. The method comprises the following steps: determining a flow unit index by utilizing analysis test data of a rock sample; clustering the flow unit indexes, and dividing the rock sample into a plurality of rock physical facies types; for each type of rock physical facies, selecting a plurality of rock samples, and establishing a standard rock sample set; well logging interpretation models of different rock physical facies are established respectively; determining an Euclidean distance between a to-be-explained reservoir section of the to-be-explained well and a flow unit index related logging curve of a reservoir section corresponding to the rock samples in the rock sample set, and determining a rock physical facies type of the to-be-explained reservoir section according to the rock physical facies type of the optimal number of rock samples with the minimum Euclidean distance; and performing well logging interpretation on the reservoir section to be interpreted by using the corresponding well logging interpretation model. According to the method, the rock physical facies are divided based on the flow unit indexes, different well logging interpretation models are established respectively, the Euclidean distance is utilized to determine the rock physical facies, and the well logging interpretation precision is improved.

This application relates to the field of tracer exploration or detection, and provides a geochemical tracing method for concealed sandstone-type uranium deposits. The method provides that by measuring the Mo and Th content in the ground atmosphere and soil, it identifies anomaly zones in the Mo element measurement, anomaly zones in the Mo-Th ratio, and comprehensive anomaly zones. Further measurement of the Mo content in the ground atmosphere is then performed in the comprehensive anomaly zones to determine favorable mineralization areas within the exploration area. According to the method provided in this application, it can effectively identify concealed sandstone-type uranium mineralization information and determine favorable uranium mineralization areas within the exploration area.

The invention relates to the technical field of low-permeability compact oil and gas field development, in particular to a variable-sequence fracturing method and device for improving the complexity of fractures between horizontal well sections. The method comprises the steps that a block variable-sequence fracturing model is constructed based on target horizontal well drilling cuttings logging response characteristics, target block coring rock mechanical parameters, target block ground stress parameters and target block construction data; based on the block variable-sequence fracturing model, determining a variable-sequence fracturing depth section of a reservoir along the path of a target horizontal well shaft; a target horizontal well variable-sequence fracturing scheme is determined by combining the target horizontal well construction process conditions and the target horizontal well shaft along-way reservoir variable-sequence fracturing section depth; and on the basis of the target horizontal well variable-sequence fracturing scheme, variable-sequence fracturing is conducted on the target horizontal well. The method is suitable for field requirements of staged fracturing transformation of various oil and gas reservoir horizontal wells, the adaptability to various lithologic reservoirs such as sandstone, carbonate rock and limestone is high, and the technical application range is wide.

The present application belongs to the field of seismic data processing, and relates to a thin sandstone reservoir prediction method and system based on prestack phase gradient attributes, comprising: S1: obtaining original seismic data, and preprocessing the original seismic data to obtain preprocessed seismic data; S2: processing the preprocessed seismic data using complex seismic trace analysis to calculate the total phase sequence of each seismic trace; S3: constructing a sandstone-mudstone thin interbedded geological model to simulate multiple configurations and obtain the characteristic law of prestack phase gradient attributes; S4: identifying the thin sandstone reservoir based on the total phase sequence and the characteristic law of prestack phase gradient attributes, realizing fluid prediction, and obtaining a prediction result; and S5: predicting the thickness of the thin sandstone reservoir through the characteristics of the prestack phase gradient attributes in the high-velocity-difference area; avoiding the thin-layer phase interference effect that cannot be solved by traditional AVO, so as to realize the purpose of super-resolution prediction of gas-containing thin sandstone.

The invention discloses a rock core description and tight sandstone reservoir sampling method based on a sedimentary structure, and belongs to the technical field of petroleum and natural gas geological exploration. The method comprises the following steps: collecting geological background data including a target stratum and logging data, and establishing a core description chart; according to the sedimentary structure profile, the core sketch and the text description established by the core description chart, the sedimentary cycle change, the sedimentary microfacies type and the lithofacies type of the target stratum coring section are obtained; and according to the sedimentary cycle change, the sedimentary microfacies type and the lithofacies type of the target stratum coring section, determining a sampling point for tight sandstone reservoir sampling. Based on the core description of the sedimentary structure, the sedimentary characteristics of the coring section can be clearly displayed in a map form, so that scientific researchers who do not carry out the work can quickly understand the sedimentary environment of a target layer and the development law of a compact sandstone reservoir, and then sampling design is carried out in a targeted manner; and a geological basis is provided for subsequent sedimentary reservoir research and exploration and development well position deployment.

The invention provides an offshore bottom water thin mutual reservoir fracturing parameter design method, and relates to the technical field of oil and gas exploitation, the method comprises the following steps: S1, determining vertical distribution of a reservoir section mud layer, a sandstone layer and a water layer according to logging data, and establishing a target well section crustal stress and rock mechanics profile; s2, acquiring the fracture toughness of rocks with different shale contents under different stresses to obtain a corrected fracture toughness profile; s3, according to the fracture half length, the fracturing displacement, the critical mudstone layer penetrating thickness corresponding to the fracturing fluid viscosity and the penetrating layer fracture height of the reservoir are initially calculated, and parameters needed for avoiding a water layer and fully transforming a thin interbed are obtained; s4, according to the fracture flow conductivity, the sand amount and the sand-carrying fluid amount are calculated initially; s5, the liquid efficiency is determined according to block fracturing historical data, the prepad fluid proportion range is initially calculated, and the prepad fluid amount is calculated; and S6, optimizing parameters through numerical simulation, and determining final fracturing parameters and a pump injection program. According to the method, the requirements of geological and offshore construction can be met, and the optimal fracturing scheme and the optimal pumping program can be rapidly determined.

The application discloses a kind of terrestrial dense reservoir carbon content evaluation method and device, comprising: using logging data to determine pure sandstone section;Fixed resistivity curve scale and adjust acoustic time difference curve scale, ensure that acoustic curve and resistivity curve coincide in pure sandstone section, obtain reference value;Based on the reference value, obtain apparent carbon content indication curve;Using multi-mineral rock volume model obtains carbon content;Establish the linear relationship between the carbon content and the apparent carbon content indication curve, obtain carbon content calculation model.The method has a reliable theoretical basis, strong operability, good practical application effect;In addition, by calculating the carbon content of reservoir, further exclude the influence of carbon content on porosity calculation result, and then accurately evaluate the porosity parameter of reservoir, provide help for geological evaluation, favorable layer selection, reserves calculation and the like.

The application provides a reservoir physical property parameter inversion method, device, equipment and storage medium, including: analyzing the basic rock physical characteristics of turbidite sandstone reservoir to obtain the properties of turbidite sandstone in the working area; correcting the soft sandstone model according to the properties of turbidite sandstone in the working area; obtaining the expression of the longitudinal wave velocity, the transverse wave velocity and the density according to the Gassmann fluid replacement equation and the corrected soft sandstone model, and constituting a rock physical model; performing reservoir physical property parameter sensitivity analysis according to the established rock physical model; inverting the reservoir physical property parameters based on the sensitivity analysis result; comparing and analyzing the inversion result with the measured curve to verify the accuracy of the result, so that the inversion result is more stable and the calculation efficiency is improved.

This invention relates to the field of oil and gas exploration technology, and discloses a method for determining the lower limit depth of sandstone reservoir exploration based on diagenetic evolution constraints. Based on the measured porosity, permeability, and corresponding measured depth of sandstone of different lithologies within the study area, compaction evolution equations and permeability evolution equations for each lithology are fitted and constructed according to the diagenetic evolution mechanism. The economic lower limit of stable daily production per well is determined according to the economic evaluation of oil and gas development in the study area. Based on oil testing data, quantitative relationships between production capacity and porosity, and between production capacity and permeability are established. The economic lower limit is converted into corresponding lower limits of reservoir porosity and permeability, which are then substituted into the compaction evolution equations and permeability evolution equations for each lithology to obtain the lower limit depth of exploration for that lithology using current technology. This invention reveals the evolution law of reservoir properties with depth for different lithologies from a genetic perspective, organically coupling economic and technical conditions with geological laws to achieve accurate and differentiated prediction of the lower limit depth of exploration.

The application discloses a method for predicting the oil and gas transportation capacity of a composite transportation system and the trap accumulation probability, belongs to the technical field of oil exploration, fully considers the whole process from the generation to the migration and accumulation of oil and gas, comprehensively evaluates the hydrocarbon supply capacity of source rocks, the vertical transportation capacity of fractures and the lateral migration capacity of sandstone transportation layers, can accurately and quantitatively evaluate the oil and gas transportation capacity of the fracture-sand body composite transportation system, and the accurate prediction of the oil and gas transportation capacity can effectively predict the trap accumulation probability and the oil and gas field scale, thereby improving the exploration success rate, especially in the low exploration degree area, the application does not need a large amount of drilled well data or the accumulation law of discovered oil and gas fields as prior information, only starts from the geological law to quantitatively study the oil and gas transportation capacity, and then predicts the oil and gas accumulation zone, and improves the success rate of exploration wells.