20 results about "Saturation distribution" patented technology

The invention discloses a rock mass fracture multi-field coupling two-phase flow analysis method and a test system, and relates to the technical field of rock fracture temperature-seepage-stress coupling action mechanism research. The analysis method comprises the following steps: saturating a crack sample with a first dyeing fluid under a target temperature and pressure condition, and obtaining a single-phase saturated flow image of the crack sample; on the basis of the single-phase saturated flow image, through optical iteration inversion calculation, obtaining fracture opening two-dimensional distribution characteristics under a target condition; under the condition of the same temperature and pressure, displacing the first dyeing fluid with the second dyeing fluid or co-flowing with the first dyeing fluid to obtain a two-phase flow image of the crack sample; performing digital image processing on the two-phase flow image and the single-phase saturated flow image, and extracting phase distribution information of the second dyeing fluid; and performing fusion analysis on the phase distribution information of the second dyeing fluid and the fracture opening two-dimensional distribution characteristics, and calculating a two-phase flow structure and saturation distribution characteristics. According to the method, rock mass fracture two-phase flow process quantitative analysis can be realized under different temperature and pressure conditions.

The invention discloses an attention mechanism fused oil field oil saturation prediction method and a related device, and belongs to the technical field of oil exploration. Collecting reservoir influence factor characteristics to obtain a data set; establishing a Ctrl-CLSTM model according to the data set, and introducing an attention mechanism; giving different attention weights to reservoir influence factor characteristics and capturing reservoir production system spatio-temporal characteristics; and taking the oil saturation, the well location distribution and the injection-production working system as input of the Ctrl-CLSTM model, and predicting to obtain an oil saturation predicted value. According to the method, the network model fusing multivariate data is constructed, an attention mechanism is introduced to screen the influence degree of external factors on the saturation spatial and temporal distribution, the oil saturation distribution rule of the oil reservoir is accurately predicted, different production system modes are dynamically regulated and controlled, and saturation distribution prediction is more accurate and practical.

The invention provides a residual oil saturation prediction method based on a percolation mechanism constraint agent model, and relates to the technical field of oil reservoir development, and the method specifically comprises the following steps: generating a water saturation field data set for an oil-water two-phase system by using an oil reservoir numerical simulator, and dividing the water saturation field data set into a training set and a test set; constructing an end-to-end proxy model based on the three-dimensional convolutional neural network and Informer; under the constraint of a seepage mechanism, training the end-to-end proxy model by using the training set; and inputting the test set into the trained end-to-end agent model to obtain a water saturation field prediction result, and drawing an image to represent remaining oil saturation distribution. According to the technical scheme, the problems of high model calculation complexity and low prediction accuracy in the prior art are solved.

The application discloses a method and device for determining gas saturation distribution of gas drive reservoir, equipment and medium. The method comprises the following steps: obtaining the static parameters of the target reservoir; determining the oil-gas phase permeation curve according to the static parameters of the reservoir, and determining the gas drive reservoir flow rate corresponding to the oil-gas phase permeation curve; constructing the gas drive reservoir gas saturation control equation of the one-dimensional homogeneous flow pipe model according to the gas drive reservoir flow rate; solving the gas drive reservoir gas saturation control equation by using the fully implicit difference method, and determining the gas drive reservoir gas saturation distribution result of the target reservoir. According to the technical scheme, the gas drive saturation simulation is realized quickly, stably and automatically by constructing the gas drive reservoir gas saturation control equation and solving the equation by using the fully implicit difference method, the dynamic analysis efficiency and precision of the gas drive reservoir are improved, and reliable data are provided for the gas drive development optimization.

The present invention discloses a method for inversely calculating the hydrate saturation in sediments by using the thermal conductivity, which includes fabricating a sediment sample containing hydrates, determining the heating time and the temperature rise of the sediment during the heating process through a temperature-measuring and heating probe, multiple groups of temperature-pressure sensor probes, and a constant-current and constant-voltage output device, then calculating to obtain the hydrate state in the sediment, and finally calculating the in-situ hydrate saturation in the sediment by using the hydrate saturation inversion formula. The present invention takes into account the influence of the latent heat of hydrate decomposition phase change when calculating the hydrate thermal conductivity, introduces the hydrate saturation in the sediment into the thermal conductivity calculation, and inversely obtains the in-situ hydrate saturation distribution in the sediment by using the principle that the thermal conductivity obtained by the mixture theory is equivalent to the thermal conductivity measured by the hot wire method. This method realizes the inverse calculation of the saturation distribution in hydrate-containing sediments with phase change based on the thermal principle, providing convenience for the calculation of the hydrate saturation in sediments.

The application provides a method and device for simulating CO2 migration based on printing method for constructing rhythmic strata, and relates to the field of underground multiphase percolation. The method comprises the following steps: according to the rhythmic characteristics of the strata, layer by layer filling fillers with different particle sizes in a visualizing cavity according to the layer thickness and fluctuation set by the parameterized boundary function, so as to form a strata model with the required rhythmic strata structure; injecting a wet phase fluid into the visualizing cavity, and after the rhythmic strata are completely immersed in the wet phase fluid, standing still and synchronously collecting the internal images of the strata model; injecting a dyed non-wetting phase fluid into the visualizing cavity from the bottom of the visualizing cavity, and synchronously collecting the internal images of the strata model; processing the collected images by a light field correction method, calculating the pixel absorbance and inverting the non-wetting phase saturation distribution. The method can reproduce complex sedimentary rhythmic layering under controllable conditions in the laboratory, and intuitively reveal the control effect of the complex rhythmic layering on CO2 migration, residual capture and dispersion risk.

The present application relates to the technical field of oil reservoir engineering, and is a method for calculating oil saturation of a horizontal section of a pilot hole converted into a horizontal well, which comprises: obtaining equivalent oil contents of light oil, medium oil and heavy oil in a horizontal section of a pilot hole converted into a horizontal well; determining an oiliness index of the horizontal section; and calculating the oil saturation of the horizontal section according to the equivalent oil contents of the light oil, the medium oil and the heavy oil and the oiliness index. The present application obtains the equivalent oil contents of the light oil, the medium oil and the heavy oil and the oiliness index of the horizontal section based on quantitative fluorescence logging technology, determines the oil saturation of the horizontal section, realizes fast and accurate acquisition of the oil saturation distribution of the horizontal section of the horizontal well, and provides a scientific basis for oilfield exploration and development and selection of fractured well sections.

The invention relates to the technical field of oil field reservoir research, in particular to a core displacement fluid in-situ dynamic inversion method and system based on multi-frequency resistance and capacitance coupling tomography, which comprises the following steps of: performing capacitance modal detection and resistance modal detection at the current time step by utilizing multi-frequency signal synchronous excitation in displacement simulation; a corresponding bimodal electric signal is obtained; fusing the bimodal electric signals according to modal optimization conditions; obtaining corresponding oil / water / gas three-dimensional saturation distribution inversion data based on the saturation inversion model; fitting is carried out based on the error between the oil / water / gas three-dimensional saturation distribution calculation data and the inversion data, and a fitting relative permeability result is output. The core displacement fluid in-situ dynamic inversion method integrating multi-modal detection, modal optimization, saturation inversion and relative permeability fitting is constructed, the cost is low, the size is small, the response frequency is high, and implementation of capacitance modal detection and resistance modal detection and inversion based on a saturation inversion model are not limited by the application environment.

The application provides an evaluation method of remaining oil re-enrichment quality, comprising the following steps: (1) obtaining the remaining oil saturation distribution before and after enrichment through remaining oil re-enrichment physical simulation or numerical simulation research; (2) calculating the flow rate curve; (3) calculating the enrichment state value distribution of the remaining oil before and after enrichment; (4) determining the evaluation index and evaluation standard of the remaining oil re-enrichment quality; and (5) evaluating the remaining oil re-enrichment quality. The evaluation method of the remaining oil re-enrichment quality of the high water cut reservoir has the characteristics of simple operation, quick calculation and clear target, can intuitively divide the remaining oil re-enriched in the high water cut reservoir into different types, thereby providing decision reference for tapping the potential of the remaining oil, and has a relatively practical engineering application value.

This invention provides a method, system, device, and storage medium for predicting sandstone permeability. The method includes: acquiring a first or second permeability prediction model; acquiring the geometric mean of the pore radius or the NMR T2 distribution within the range of transverse relaxation time >40ms corresponding to a cumulative mercury saturation of 20% for the target sample, as well as the cumulative mercury saturation distribution of the high-pressure mercury intrusion pore size or the cumulative percentage distribution of the NMR pore size; acquiring the lower limit of the pore size of the movable fluid storage space of the target sample and using it as the boundary point for fractal analysis; combining the aforementioned cumulative mercury saturation distribution of the high-pressure mercury intrusion pore size or the cumulative percentage distribution of the NMR pore size to determine the first or second fractal dimension of the target sample; determining the permeability of the target sample using the first permeability prediction model based on the aforementioned pore radius and first fractal dimension, or determining the permeability of the target sample using the second permeability prediction model based on the aforementioned geometric mean and second fractal dimension.

This invention relates to the field of oilfield reservoir research technology, specifically a method and system for in-situ dynamic inversion of core displacement fluids based on multi-frequency resistive and capacitive coupled tomography. The method includes: synchronously exciting capacitive and resistive modes at the current time step using multi-frequency signals during displacement simulation to obtain corresponding dual-mode electrical signals; fusing the dual-mode electrical signals according to mode optimization conditions; obtaining corresponding three-dimensional saturation distribution inversion data for oil / water / gas based on a saturation inversion model; and fitting the error between the calculated and inverted data based on the three-dimensional saturation distribution of oil / water / gas to output the fitted relative permeability result. This invention constructs an in-situ dynamic inversion method for core displacement fluids integrating multi-mode detection, mode optimization, saturation inversion, and relative permeability fitting. It is low-cost, compact, and has a high response frequency. Furthermore, the implementation of capacitive and resistive mode detection and the inversion based on the saturation inversion model are not limited by the application environment.

The invention discloses a system and method for measuring fluid saturation in a two-dimensional visual model, and the system comprises an injection module which is used for injecting experiment water with a first color and experiment oil with a second color into a model module; the photographing module is provided with a photographing part and a light source; the model module is arranged on the side surface of the photographing part irradiated by the light source; the data processing module is used for controlling the photographing part to continuously photograph saturated water images for recording the current saturation process when the experimental water is saturated, calculating the light transmission intensity of the model to the second color according to the saturated water images, and then outputting the light transmission intensity of the model to the second color; and the control part is used for controlling the photographing part to continuously shoot oil-water two-phase images for recording the current saturation process when the experimental oil is saturated, and calculating the light transmission intensity of the model to the first color component and the second color component according to the oil-water two-phase images, so that the water content and oil saturation distribution is calculated according to the light transmission intensity data.

The invention relates to the technical field of gas field development dynamic monitoring, in particular to a remaining oil saturation distribution high-precision real-time monitoring method based on distributed optical fibers. The method comprises the following steps: acquiring a continuous shaft real-time temperature profile based on distributed temperature sensing devices arranged in a plurality of monitoring wells; inputting the data into a shaft-oil reservoir coupling model constructed based on the law of conservation of mass, momentum and energy to carry out nonlinear inversion, and accurately calculating a layered flow profile along the well depth direction; deducing an oil saturation profile of a stratum corresponding to each well according to a multiphase seepage mechanism by combining the layered flow and a preset oil-water relative permeability curve; and finally, projecting each well profile to a three-dimensional geological grid through multi-well linkage, updating in real time, and constructing a three-dimensional remaining oil saturation distribution field of the target oil reservoir, thereby realizing continuous, real-time and high-precision three-dimensional online monitoring on the remaining oil saturation of the whole oil reservoir.

The invention discloses a method for accurately monitoring saturation distribution of hydrates in sediments, and the method comprises the steps: building a resistivity and sound wave collection device which comprises a hydrate sample preparation module, a pressure test module, a temperature test module, a resistivity parameter test module and an acoustic parameter test module; carrying out a simulation experiment to obtain temperature, pressure, sound wave and resistance data; converting the measured resistance data into two-dimensional resistivity data by using a resistivity tomography technology; utilizing the optimized acoustic rock physical model to inversely calculate the hydrate saturation; optimizing the resistivity inversion hydrate saturation based on the calculated hydrate saturation and the obtained two-dimensional resistivity data to obtain two-dimensional saturation data; and based on the two-dimensional saturation data, establishing a three-dimensional image of the hydrate saturation by adopting a sequential Gaussian simulation method. According to the method, the calculation precision of the hydrate saturation is improved, the distribution of the hydrate saturation is accurately imaged, and data support is provided for hydrate reservoir evaluation.

This invention belongs to the field of oil and gas development, specifically relating to a method for characterizing reservoir water cut distribution. The method includes: establishing oil-water phase permeability curves based on experiments measuring the relative permeability of two-phase fluids in rocks; combining this with reservoir water saturation data to obtain oil phase relative permeability field data and water phase relative permeability field data; establishing fitting relationships between crude oil viscosity and reservoir pressure, and between crude oil volume coefficient and reservoir pressure, based on reservoir fluid property analysis experiments; combining this with reservoir pressure data to obtain oil phase viscosity field data and oil phase volume coefficient field data; establishing a water cut calculation formula; and establishing a reservoir numerical model based on the calculation formula to generate a water cut distribution map. The water cut distribution map generated using this method can characterize the water cut distribution at different stages of reservoir development, providing a more refined representation of reservoir water cut distribution and potential, and offering a more scientific basis for evaluating water drive development effectiveness and formulating reservoir adjustment plans.

The invention provides a CO2 migration simulation research method and device for constructing a rhythm stratum based on a printing method, and relates to the field of underground multiphase seepage. Comprising the following steps: filling a visual cavity with fillers with different particle sizes layer by layer according to stratum rhythm characteristics and layer thickness and fluctuation set by a parameterized boundary function to form a stratum model with a required rhythm stratum structure; wet-phase fluid is injected into the visual cavity, the rhythm stratum is completely immersed in the wet-phase fluid and then stands still, and an internal image of the stratum model is synchronously collected; injecting a dyed non-wetting phase fluid into the visual cavity from the bottom of the visual cavity, and synchronously acquiring an internal image of the stratum model; and processing the acquired image through a light field correction method, calculating pixel absorbance and inverting non-wetting phase saturation distribution. According to the method, the complex deposition rhythm bedding can be reproduced under the controllable condition of a laboratory, and the control effect of the complex rhythm bedding on CO2 migration, residue capture and dissipation risks is visually revealed.

The invention relates to an oil saturation distribution measuring method suitable for an open system, which comprises the following steps: dyeing non-wetting phase oil, keeping wetting phase water colorless, and when the dyed oil is injected into a visual seepage model of saturated water, measuring the oil saturation distribution of the open system. An oil phase greatly absorbs a spectrum which does not correspond to the color of the oil phase, a linear relation exists between the light intensity attenuation of the spectrum and the corresponding oil quantity, and a quantitative relation between the light intensity attenuation and the corresponding oil quantity is established through dynamic calibration, so that a calibration coefficient is obtained and used for calculating the oil saturation distribution in the medium. According to the fluid saturation measuring method provided by the invention, the saturation and the optical signal have a good linear relationship, and the measuring precision is high.

The present invention relates to the field of oil and gas production engineering technology, and more specifically, to a machine learning-based electromagnetic method for predicting the saturation field of oil reservoirs during the high-water-cut period. The method combines a machine learning algorithm with well-surface electromagnetic saturation field testing. Based on the single-layer saturation field distribution obtained by well-surface electromagnetic testing, it introduces reservoir flow correlation parameters and utilizes various regression algorithms in machine learning to predict the saturation distribution of the entire vertical reservoir, ultimately generating accurate prediction results for the fluid flow in high-water-cut oil reservoirs.

The application discloses a kind of multi-span reservoir remaining oil saturation prediction methods based on time condition generative adversarial network.The method uses reservoir numerical simulation to obtain monthly scale remaining oil saturation distribution field, and it is mapped as two-dimensional grid image;With the remaining oil saturation image of continuous historical time as input, with the remaining oil saturation image corresponding to different prediction time span as output target, the prediction time span Δt is encoded as condition vector, while input generator and discriminator, in the generator bottleneck layer, the intermediate characteristics are modulated by characteristic linear modulation module, realize the unified prediction of single model to multiple time span;Discriminator discriminates the prediction result under the condition of corresponding time span.In the training process, the joint optimization is carried out using the adversarial loss, pixel loss, feature matching loss and gradient consistency loss.The method can improve the consistency of multi-time span prediction, reduce the long-span prediction error, and improve the spatial structure stability.

The invention relates to a CO2 expansion direction dynamic determination method, device and system based on Walkaway-VSP. The method comprises the following steps: acquiring geological data of a target area, and constructing a geology-geophysics comprehensive model based on the geological data; carrying out secondary mining processing on the geological data to obtain threatened information including geological dynamic change of the target area; determining CO2 distribution models of different CO2 injection stages, and determining a basic observation parameter type of each CO2 injection stage by using the CO2 distribution models; inputting the collected basic observation data corresponding to the type of the basic observation parameter and the precursor information into the decision tree model which completes training to obtain a target observation parameter; acquiring target seismic data of the target area based on the target observation parameters; and performing joint inversion based on the target observation parameters and the target seismic data to obtain CO2 saturation distribution, and determining the CO2 expansion direction based on the CO2 saturation distribution. According to the scheme, the determination accuracy of the CO2 expansion direction is improved.