84 results about "Saturation distribution" patented technology

The invention relates to a multi-scale processing method for nuclear logging data, comprising 1, reading logging data; 2, carrying out filtering for logging data; 3, carrying out normalization processing for filtered data; 4, carrying out multi-scale decomposition, amalgamation and reconstruction for logging data after normalization processing; and 5, displaying curve and image. The invention solves the limitation that collected data can be process and interpreted only in 1-D depth region in prior technology. The invention can reflect multi-scale characteristic for oil gas water distribution in multi-dimension space and improve accuracy for describing distribution of residual oil gas saturation.

An endoscopic diagnosis system accurately calculating the oxygen saturation level considering the effects of the blood vessel depth and the blood amount and displaying an oxygen saturation level distribution in simulated colors includes an endoscope device for illuminating a subject, imaging reflected light, and acquiring image signals corresponding to three or more reflected light having a wavelength range of 460 to 700 nm including a first and a second image signal corresponding to reflected light having two wavelength ranges where the light absorption coefficient changes according to the blood hemoglobin oxygen saturation level and a third image signal corresponding to reflected light having one wavelength range where the light absorption coefficient does not change; a blood amount-oxygen saturation level calculator using the acquired image signals for calculation; and a display for displaying an oxygen saturation level distribution based on the oxygen saturation level information.

The invention discloses a saturation distribution type denial-of-service attack method and a saturation distribution type denial-of-service attack system in a defense dynamic website. Data stream is automatically switched to a hidden spare link under saturation distribution type denial-of-service attack, and is automatically switched to an original main link when the saturation distribution type denial-of-service attack is cancelled. With the adoption of the saturation distribution type denial-of-service attack method and the saturation distribution type denial-of-service attack system in the defense dynamic website provided by the invention, the problem that dynamic data cannot be accessed under the saturation distribution type denial-of-service attack in prior art can be solved. The saturation distribution type denial-of-service attack method and the saturation distribution type denial-of-service attack system in the defense dynamic website provided by the invention can be applied to various fields such as electronic government affairs, electronic commerce, negotiable securities and bank in need of carrying out dynamic data transmission under the saturation distribution type denial-of-service attack, and has a wide application prospect.

The invention provides a method and a device used for hydrocarbon quantitative prediction and based on an unconsolidated sandstone model. The method comprises the steps of obtaining background information of reservoir rock, according to the background information of the reservoir rock, calculating a dried rock modulus of the constant-cement unconsolidated sandstone model, calculating vertical and horizontal wave speeds of constant-cement unconsolidated sandstone when water is saturated, arranging a porosity degree and saturation level distribution range according to the constant-cement unconsolidated sandstone model, calculating formulas that a shear modulus corresponding to each porosity degree and saturation level and the horizontal wave speed are divided by density, building a rock physical template where a parameter that the shear modulus is divided by the density and a parameter that the horizontal wave speed is divided by the density are jointed, carrying out pre-stack synchronous inversion on earthquake pre-stack trace gathering, enabling the obtained shear modulus and the horizontal wave speed during the inversion to be divided by the density and projected to the rock physical template where the parameter that the shear modulus is divided by the density and the parameter that the horizontal wave speed is divided by the density are jointed, calculating the porosity degree and the saturation level of a target reservoir by a template mapping method, and judging an oil-gas distribution condition of the target reservoir. The method and the device used for the hydrocarbon quantitative prediction and based on the unconsolidated sandstone model improve prediction accuracy of the effective reservoir.

The present invention provides a changing-streamline well pattern adjusting method of an oil reservoir in the stage after polymer flooding in the oilfield development process. The changing-streamline well pattern adjusting method after polymer flooding includes the steps that fine geological research is performed, and a fine oil reservoir three-dimensional geological model is established; a numerical simulation model is established, and the saturation distribution rule of remaining oil is analyzed; feasibility analysis for series-of-strata well pattern adjustment is performed; a changing-streamline well pattern adjusting scheme is designed; index prediction of the scheme is performed with an oil reservoir numerical simulation method, and an optimal scheme is selected. The changing-streamline well pattern adjusting method after polymer flooding has very good practicability for gradual decrease of yield of the oil reservoir in the extra-high water containing period after polymer flooding and acceleration of oil production, the oil production rate in the extra-high water containing period after oil reservoir polymer flooding can be effectively and economically improved, and the cumulative oil production of maturing oil fields is substantially increased.

The invention provides an injection-production relation optimizing and adjusting method for a well group and belongs to the field of oil field development projects. According to the injection-production relation optimizing and adjusting method for the well group, a three-dimensional phase-control geologic model of a block to be adjusted is established by drawing a depositional microfacie distribution diagram, a sand group structural map, an effective thickness contour diagram, a porosity contour diagram and a permeability contour diagram of the block to be adjusted, the remaining oil saturation distribution state of the well group in the block to be adjusted is determined, and the injection-production relation of the well group in the block to be adjusted is optimized and adjusted. Through depositional microfacie control, the geologic model which is more similar to the actual stratum is established, the influence of depositional microfacies is fully considered during numerical simulation of the well group, permeability saturation curves corresponding to the percolation characteristics of different depositional microfacies are provided for the different depositional microfacies, and the simulated remaining oil distribution states in different facie belts are more accurate. Well group adjustment parameters obtained on the basis are more reliable, and a more objective theoretical basis is provided for continuous and efficient development of oil fields and scientific decision-making.

The invention discloses a tight sandstone reservoir rock elasticity modulus calculation method. The method includes analyzing characteristics of a conventional sandstone reservoir and tight sandstone reservoir respectively according to rock physical parameters; researching the main characteristics of low porosity, low pore connectivity and high irreducible water saturation of the tight sandstone; analyzing pore shapes and pore distribution features of the rocks on the basis of a rock physical model sensitive to the inclusion shape; considering the simultaneous existence of the fluid even mixing and patchy saturation distribution, combining with an attenuation model to analyze the problem that earth physical data produced in manners of low permeability and high viscosity are match mutually in different frequency bands, and applying a rock physical module established according to the tight sandstone reservoir to reservoir rock speed estimation.

A multi-scale method to efficiently determine the fine-scale saturation arising from multi-phase flow in a subsurface reservoir is disclosed. The method includes providing a simulation model that includes a fine-scale grid defining a plurality of fine-scale cells, and a coarse-scale grid defining a plurality of coarse-scale cells that are aggregates of the fine-scale cells. The coarse-scale cells are partitioned into saturation regions responsive to velocity and/or saturation changes from the saturation front. A fine-scale saturation is determined for each region and the saturation regions are assembled to obtain a fine-scale saturation distribution. A visual display can be output responsive to the fine-scale saturation distribution.

The present invention relates to an apparatus for simulating a water-rock reaction, and a method for simulating a water-rock reaction by using the apparatus. The apparatus comprises: a micro CT scanning system; a reaction kettle arranged inside the micro CT scanning system; a fluid injection system connected to the inlet of the reaction kettle; a fluid ion test analysis system connected to the outlet of the reaction kettle; and a data collecting and processing system for collecting the data of the micro CT scanning system and the fluid ion test analysis system. According to the present invention, the apparatus can monitor the dynamic process of the water-rock reaction, can perform real-time in-situ image monitoring on the water-rock reaction, can real-timely monitor the diffusion distribution trend, the saturation distribution and other parameters of the fluid in the pores, and can provide important scientific significance for the monitoring of the reaction progress of the water-rock reaction experiment system and the exploration of the fluid-rock interaction law; and the method can simultaneously complete image and quantitative calculation, has high real-time online monitoring degree, and is convenient for application promotion.

The objective of the present invention is to offer an image processing apparatus, or an image processing program which can generate natural images. In the invention, a chroma saturation correction coefficient is determined according to the chroma saturation distribution properties of an input image, and the chroma saturation correction is executed based on the determined coefficient. Therefore, a suitable chroma saturation correction can be performed to various input images. To achieve above objective, in the image processor 100, the chroma saturation distribution properties calculator 101 calculates chroma saturation distribution properties from an input image signal. The chroma saturation correcting gain calculator 102 calculates the standard chroma saturation correcting gain, which is a coefficient used as a standard for calculating the chroma saturation correction quantity based on the properties of the input image signal. The chroma saturation correction executor 103 corrects the chroma saturation based on the calculated correcting gain.

A method with application for evaluation or production of a reservoir for determining multiphase flow parameters of a porous medium such as a rock, from the interpretation of displacement experiments. From an injection experiment on a rock sample, the saturation profiles are measured in different sections of the sample. The experimental data are then subjected to a preliminary interpretation by means of a numerical simulation code allowing production of simulated pressure profiles. These profiles are then combined with the measured saturation profiles so as to evaluate the local properties of the sample in terms of capillary pressure. These properties are then re-injected into the simulator as input data so as to finely interpret the flow parameters while respecting the evolutions of the differential pressure, of the displaced fluid production and of the saturation profiles.

The present disclosure proposes a method and an electronic device for detecting glare pixels of an image including an object and an electronic device using the same. The method includes the following steps. First, the image is processed to remove overexposed pixels from the image to generate a first image. The first image is processed to remove non-object pixels from the first image to generate an object pixel image. The glare pixels are detected from the object pixel image according to a saturation distribution threshold and an intensity distribution threshold. The present disclosure is able to adjust the saturation distribution threshold and the intensity distribution threshold dynamically and adaptively to satisfy various kinds of objects and ambient lighting conditions so as to improve the probability of successful detection and reduce the probability of false alarms on the glare pixels.

A saturation detecting means (200) detects saturation at every pixel in a digital color image or at every coordinate point in an analog color image. A saturation conversion control means (300) determines the saturation conversion condition for the pixel or coordinate point based on the detected saturation. A saturation conversion processing means (400) implements saturation conversion in such a manner that saturation is reduced for the areas with low saturations in the color image, so as to enlarge the difference in saturation relative to the areas with high saturations, thus achieving improved saturation contrast. Further, the distribution of saturations in the input image is automatically extracted, so as to determine the threshold for deciding a saturation suppressed area based on the distribution of saturations. In this way, in order to obtain a color image improved in vividness and presenting feeling of sharpness, the saturation contrast is automatically improved.

The invention discloses a seepage experiment method for a water drive profile model of an edge water sandstone gas reservoir. The method comprises (1) combining adjacent well sections with similar permeability in a reservoir stratum into a single layer according to the similarity ratio of the total thickness of the reservoir stratum to the height of a physical plate model and scaling the single layer on the plate model; (2) making the plate model; (3) making a section sand filling model, filling quartz sand into a groove of the plate model according to the actual reservoir stratum profile sequence for cementing, and placing an impervious partition at the corresponding position of the sand filling model; (4) establishing or controlling the reservoir stratum opening degree; (5) restoring theoriginal state of the gas reservoir; (6) establishing an edge water system; (7) controlling the recovery yield and simulating the gas mining process; (8) conducting data processing to obtain a waterintrusion profile visual saturation distribution map and the gas recovery rate. According to the method, the principle is reliable, the operation is simple, a measurement result is intuitive, the water body propulsion situation in the development process of the edge water gas reservoir can be simulated, and the technical means for the efficient development of the gas reservoir is provided.

A method for determining for a reservoir (1) containing fluids (W, O), the variation in the relative permeability (krO, krW) of at least one of the fluids, as a function of the saturation of at least one of the fluids (W, O),) is provided. According to this method a saturation distribution of one of the fluids of the reservoir is determined on the basis of a measurement of a physical property in the reservoir. A dynamic model (20) for the flow of fluids in the reservoir (1) is created. The dynamic model generates a saturation distribution. The saturation distribution (40) generated by the dynamic model is compared with saturation distribution obtained from measurement. The dynamic model (20) is updated with intermediate relative permeability values (krO)_i and (krW)_i and steps b and c are repeated if the saturation distribution generated by the dynamic model and that determined on the basis of measurement do not coincide.

The invention provides a shale gas saturation determination method, device and equipment based on deep learning, and the method comprises the steps of obtaining the fracture permeability and target moment of a target stratum; converting the fracture permeability into equivalent matrix permeability to obtain equivalent permeability data of the target stratum; determining a target equivalent permeability field diagram of the target stratum according to the equivalent permeability data; and according to the target equivalent permeability field diagram and the target moment, determining a saturation field diagram of the target stratum at the target moment by utilizing a target deep convolution decoding network. In the embodiment of the invention, a solving problem of an uncertainty equation can be converted into a graph-graph regression problem by utilizing a target deep convolution solution coding network, and a relationship among a permeability field graph, a target moment and a saturation field graph is established. And the resolution of the image can be reduced through the target deep convolution decoding network, so that the calculation efficiency can be effectively improved, andthe technical effect of efficiently and accurately predicting saturation distribution is achieved.

The invention discloses a method for determining the migration velocity of a displacement front in CO2 miscible displacement physical simulation, belonging to the detection field of oil pool physical simulation. The method for determining the migration velocity of a displacement front in CO2 miscible displacement physical simulation comprises the following steps of: firstly, determining the oil saturation distribution in different positions in a porous medium by use of the imaging technology; obtaining the oil saturate change curve in a sand filling model in the imaging view field; then, determining the characteristic moment point passing through the imaging view field of the displacement front; and finally, obtaining the migration velocity of the displacement front by use of an analysis method. The method can determine the migration velocity of the displacement front in the CO2 miscible displacement process and accurately obtain the flowing law of CO2 in the oil-containing porous medium so as to provide analysis basis for the nondestructive detection in the CO2 miscible displacement physical simulation process.

A method and machine-readable medium for adjusting image saturation is disclosed. A designation of a change in a selected saturation distribution value of an image is received from a user. A saturation curve is automatically generated on a saturation histogram so that the saturation curve passes through the changed saturation distribution value. Saturation of the image is automatically adjusted based on the saturation curve.

The invention provides an apparatus for dynamically adjusting the saturation of an image signal consisting of a plurality of pixels. The apparatus includes a first transformation module, an operation module, a gain module, an adjustment module and a second transformation module. The first transformation module transforms the pixels of the image signal into a plurality of intermediate signals, where each of the intermediate signals has a respective saturation value. The intermediate signals are adjusted in accordance with a gain signal determined by a histogram relative to the saturation distribution of the intermediate signals. The adjusted intermediate signals are transformed back into the pixels of the image signal, thereby the saturation of the image signal is adjusted.