69 results about "Well test" patented technology

The invention provides a shale gas well inter-well pressure channeling identification method, system, device and medium, the shale gas well inter-well pressure channeling identification method comprises the following steps: carrying out well test analysis in a pump stop pressure drop stage after fracturing, and collecting data; the bottom hole pressure is calculated, and pressure data oscillation caused by the water hammer effect is eliminated; drawing a pressure difference and pressure difference derivative double logarithmic curve based on the bottom hole pressure data; establishing a shale gas well non-uniform fracture multi-zone coupling well test seepage model; the model parameters are adjusted, a pressure difference and pressure difference derivative double logarithmic curve is fitted, and when the model result is close to the drawn pressure difference and pressure difference derivative double logarithmic curve, the crack parameters of the model parameters are obtained through inversion; judging whether the crack parameter is too high or not; and determining the relationship between the child well group and the mother well group, analyzing the pressure difference and pressure difference derivative curve morphological characteristics of the fracture parameter high section, and judging whether pressure channeling occurs or not. The system can realize the method. According to the method, the inter-well pressure channeling identification efficiency in the well group synchronous fracturing period can be improved.

The application discloses a kind of faulted dissolution body reservoir oil well producing depth acquisition method, device, equipment and medium.Faulted dissolution body reservoir oil well producing depth acquisition method includes: obtaining the temperature well testing monitoring data of target faulted dissolution body reservoir oil well;Temperature well testing monitoring data is handled, and actual temperature well testing interpretation curve is obtained;Temperature well testing model of target faulted dissolution body reservoir oil well is constructed, and the theoretical temperature well testing interpretation curve corresponding to multiple heat transfer distances is obtained based on temperature well testing model;Comparative analysis actual temperature well testing interpretation curve and theoretical temperature well testing interpretation curve, the heat transfer distance corresponding to the theoretical temperature well testing interpretation curve most matched with actual temperature well testing interpretation curve is determined as the producing depth of target faulted dissolution body reservoir oil well.Using the present application can reduce the uncertainty of faulted dissolution body reservoir producing depth calculation, improve the accuracy of producing depth calculation.

The invention discloses a water invasion oil and gas well productivity prediction method and system based on well test interpretation and seepage theoretical calculation, and relates to the technical field of oil and gas reservoir development. The method comprises the following steps: establishing a gas well test interpretation model based on well test data; performing historical data fitting on the gas well test interpretation model to obtain a productivity well test indication curve; analyzing the characteristics of a productivity well testing indication curve, and introducing additional pressure loss coefficient and laminar flow item coefficient correction based on a seepage mechanics theory to obtain a plane radial non-Darcy seepage productivity evaluation model of the water-invaded gas well; and building a block well type and stratified system correlation coefficient correction chart based on a non-Darcy seepage productivity evaluation model, and guiding reasonable production allocation and injection allocation of the oil and gas field / gas storage well. Rapid and reasonable production allocation and injection allocation of the water-invaded gas well can be achieved, the cost is reduced, the efficiency is improved, the number of well testing times is greatly reduced, and reasonable and efficient operation of oil-gas field development / gas storage injection and production is guaranteed.

The invention discloses offshore exploratory well testing and draining equipment and a metering method, and the offshore exploratory well testing and draining equipment comprises a liquid supply device, an underground device and a separation metering device, and further comprises a temperature difference energy thermal circulation device. The temperature difference energy heat cycle device comprises a steam generation assembly, a power generation assembly and a heating assembly; the steam generation assembly is used for generating steam by utilizing temperature difference energy of surface seawater and deep seawater; the power generation assembly is used for generating power through steam and supplying power to the heating assembly. The heating assembly is used for heating working fluid supplied into the downhole device. The working liquid heated to the preset temperature is supplied into the underground device and mixed with the produced liquid, the temperature of the mixed liquid of the produced liquid and the working liquid is increased, the viscosity of the mixed liquid is reduced, the mixed liquid is smoothly discharged to the separation metering device through the liquid outlet, and the problems that the temperature difference of an offshore exploratory well is large, the produced liquid is attached to the inner wall of a shaft due to low temperature, and productivity evaluation is affected are solved.

This invention relates to the field of well test interpretation technology, and discloses a method and related equipment for calculating the length of large-scale natural fractures. By establishing a mathematical model of well test in a naturally fractured reservoir, calculating the real-time bottom hole pressure, and plotting the interpretation curve of the well test in the naturally fractured reservoir, the theoretical bottom hole pressure is obtained by combining the real-time bottom hole pressure and the interpretation curve, and the theoretical well test curve is plotted. Finally, the natural fracture length is obtained by fitting the theoretical and measured curves. This method overcomes the limitation of uniform fracture distribution in conventional models, is suitable for deep gas reservoirs with poor matrix properties and strong fracture heterogeneity, and avoids the problem of only being able to obtain equivalent parameters and interpreting parameters that do not reflect reality. It accurately characterizes the fracture development state and improves the accuracy of well test interpretation.

The invention provides a method for determining the permeability and porosity of a karst cave main body in an interlayer karst area, and the method comprises the steps: collecting the data of a research area, and determining a single well belonging to a single fracture-cave body; single-well test interpretation is conducted, and the inner area permeability and the outer area permeability of single-well test interpretation are determined; establishing a first relation model by utilizing the inner area permeability and the outer area permeability, establishing a fracture zone well logging interpretation model by utilizing the research area data, and performing fracture zone permeability well logging interpretation; and obtaining the cave main body permeability through the first relation model and the fracture zone permeability. The porosity determination method comprises the following steps: determining the permeability of the karst cave main body by adopting the permeability determination method; and establishing a second relation model by utilizing the research area data, and obtaining the porosity of the karst cave main body through the second relation model and the permeability of the karst cave main body. According to the method, values are accurately assigned to the porosity and permeability of the interlayer karst fracture-cavity body, and important reservoir physical property parameters are provided for efficient development of the fracture-cavity type carbonate reservoir.

The application discloses a method and device for determining percolation characteristics of a reservoir, and belongs to the technical field of oil and gas reservoir exploration and development. The application divides different reservoir space matching types by the structural characteristics and distribution characteristics of the reservoir space in a core, constructs a corresponding reservoir conceptual model for each reservoir space matching type, establishes a corresponding percolation model for different types of reservoir spaces in the reservoir conceptual model, and obtains the pressure response of the outlet end of different reservoir conceptual models in the process of solving the percolation model, so as to draw a well test characteristic curve, and determine the corresponding relationship between different reservoir space matching types and percolation characteristics according to the well test characteristic curves of different reservoir conceptual models, thereby providing support for the identification and evaluation of multiple medium reservoirs.

The application belongs to the technical field of oil and gas field development, and particularly relates to a porosity determination method, device, electronic equipment and storage medium. The porosity determination method comprises the following steps: obtaining seismic data and measured well data of a target area; establishing a geometric structure model of a fracture-vug type reservoir according to the seismic data; establishing a three-dimensional numerical well test model according to the geometric structure model and a corresponding fluid model; obtaining bottom hole pressure simulation data in the three-dimensional numerical well test model; and determining target porosity of the target area according to the bottom hole pressure simulation data and the measured well data. The application establishes a geometric structure model of a fracture-vug type reservoir through seismic data of a target area, then establishes a three-dimensional numerical well test model according to the geometric structure model, and finally determines target porosity of the target area by comparing bottom hole pressure simulation data of the three-dimensional numerical well test model with measured well data, thereby solving the problem of porosity assignment of a fracture-vug type reservoir.

The invention discloses a deepwater high-pressure well test system, and the system comprises an acquisition module which comprises a plurality of pressure sensors and is used for acquiring the pressure of different positions in a deepwater high-pressure well; the input end of the optimization module is electrically connected with the output end of the acquisition module, and the optimization module is used for optimizing the acquired data; the input end of the processing module is electrically connected with the output end of the optimizing module, and the processing module is used for judging the high-voltage leakage condition; the input end of the output module is electrically connected with the input end of the processing module; the invention further discloses a deepwater high-pressure well testing method, the underground high-pressure leakage condition can be judged, and the phenomenon of overpressure damage or explosion to downstream equipment due to the fact that high pressure is kept in the low-pressure process is prevented.

This invention provides a construction method for deep exploration well testing, relating to the field of deep exploration well testing technology, including: Step 1, installing and pressurizing a test blowout preventer (BOP) assembly, and performing well cleaning operations after the pressure test is passed; Step 2, performing perforation operations using a tubing-transfer perforation method; Step 3, removing the perforation tubing; Step 4, running in a combined stimulation-testing process tubing; Step 5, disassembling the test BOP assembly and installing a gas production wellhead; Step 6, performing test extrusion and acidizing operations; Step 7, performing fluid drainage, sampling, and production assessment; This method solves the problems of low success rate, long construction period, and high construction cost in existing deep exploration well testing construction techniques.

Disclosed are methods, systems, and computer programs for generating petrophysical analysis data. The methods include: accessing first porosity data and first well log data associated with an NMR well; randomly selecting data elements comprised in the first porosity data and the first well log data; developing, based on the randomly selected first porosity data and first well log data, a learning data structure; generating, based on the learning data structure, a machine learning model; receiving second well log data using sensor(s) deployed about a non-NMR well; adapting, based on the second well log data, variable input parameters of the machine learning model to generate second porosity data; and formatting the second porosity data to generate petrophysical analysis data. The petrophysical analysis data indicates one or more of: a petrophysical characterization of a rock type; flow dynamic data of a carbonate reservoir; well test or perforation zone data; and pore data.

The present application belongs to the field of oil and gas field development and intelligent measurement technology, and specifically discloses a shale gas single well AI measurement method and system, which comprises cutting into a single well test separator, obtaining gas production and liquid production measured data and correcting oil and gas reservoir mechanism model parameters; calculating the bottom hole flowing pressure and theoretical gas production and constructing a gas production trend prediction model; switching the single well to a production separator for mixed transportation production, real-time acquisition of wellhead operating parameters, calculation of single well gas production and prediction value by using the oil and gas reservoir mechanism model and the gas production trend prediction model; judging the single well production state and calculating the error level between the prediction value and the measured value; automatically generating a test rotation plan according to the single well production state and the error level, adjusting the test priority and frequency of the single well; and using the new measured data obtained by the rotation test to iteratively update the oil and gas reservoir mechanism model parameters and the gas production trend prediction model. The present application solves the problems of large error, high cost and dependence on manual operation of the existing measurement technology.

The invention discloses a natural gas well productivity prediction and well test analysis method and system, and belongs to the technical field of natural gas related basic theory research. The method is based on related theories of mathematical physical equations and combines seepage characteristics of real gas in a porous medium in a natural gas well; according to the method, a natural gas nonlinear unstable seepage partial differential equation is established, a dimensionless transformation function of pressure, time and position defined based on a differential quotient is introduced, an analytical solution of the nonlinear seepage equation considering the turbulence effect is obtained, the productivity of a natural gas well is predicted, well testing data is analyzed, and well testing model calculation shows that the yield of the natural gas well is greatly improved. After the inertia-turbulence effect is considered, the bottom hole pressure is lower; the calculation of a fixed bottom hole flowing pressure model shows that the gas well yield is reduced after the inertia-turbulence effect is considered; compared with an existing method, the result has the advantages that errors are reduced, the precision is higher, and a certain theoretical basis can be provided for further researching the problem of unstable seepage of the complex heterogeneous oil and gas reservoir.

This invention discloses a method for determining the production capacity of a coalbed methane (CBM) well without shutting it in. The method includes: acquiring basic data of the CBM well; determining a relationship table between pressure and CBM deviation factor, and a relationship table between pressure and apparent pressure, based on CBM PVT experimental data; recording the daily gas production, bottom hole pressure, and cumulative gas production of the CBM well at each stable flowing pressure test moment during three or more different production stages; determining the formation pressure corresponding to each stable flowing pressure test moment using a mass balance equation; determining the coefficients of the CBM well's production capacity equation based on the formation pressure, bottom hole pressure, and production at each stable flowing pressure test moment, thereby obtaining the CBM well's production capacity equation; and substituting the formation pressure and bottom hole pressure values ​​into the production capacity equation and solving for the corresponding CBM well production capacity. This invention effectively overcomes the shortcomings of traditional well testing methods that require shutting in the well to test formation pressure, and avoids the problem that the applicable conditions of existing non-shutdown methods for determining gas well production capacity equations are difficult to meet.

The invention relates to the technical field of well test interpretation, in particular to a carbon dioxide flooding phase state interactive seepage well test interpretation method which comprises the steps that a three-area composite seepage model of an injection well and a radial composite seepage model of a production well are solved; and explanation: drawing a corresponding pressure derivative curve according to each explanation method, respectively explaining by utilizing each well test explanation method, and taking the mutually matched explanation results as well test explanation results. According to the method, multiple well test interpretation methods are combined for mutual verification, the accuracy of interpretation results is improved, the multiplicity of the interpretation results is reduced, in addition, effective interpretation results can be obtained through the early well test interpretation method for the test wells which do not show radial flow and linear flow characteristic sections due to the fact that the well shut-in pressure recovery time is short, and the well test efficiency is improved. Compared with a traditional interpretation method, the early well test interpretation method has the advantages that the multiplicity of interpretation results is remarkably reduced, and a reliable basis is provided for carbon dioxide flooding miscible phase development.

The application discloses a weak gel profile control reservoir four-dimensional well testing interpretation method and device, which is based on fluid percolation theory in porous media, and is a kind of weak gel profile control reservoir four-dimensional well testing forward and inversion algorithm established and solved according to mathematical physics method.According to the method, the fluid parameter distribution in the detection radius range around the well can be inverted by using the measured pressure data of the well testing after weak gel profile control, and then the weak gel viscosity distribution after profile control is obtained.Through the experimental data of the relationship between weak gel viscosity and concentration, the weak gel concentration distribution in the detection radius range around the well can be inversely solved by using the weak gel viscosity distribution.And through the weak gel concentration peak value in the distribution graph, the weak gel profile control plugging position can be determined.The weak gel profile control reservoir four-dimensional well testing forward and inversion algorithm established by the application solves the problem that the weak gel concentration distribution of the weak gel profile control reservoir plugging position is difficult to determine, and provides a theoretical basis for the next step of profile control scheme.

The application discloses a method for identifying remaining reserves distribution of a water-bearing gas reservoir, and belongs to the technical field of oil and gas field development. S1, a water body at the edge of a gas reservoir and internal gas wells are equivalent to separate units, and initial control volumes of each unit and between the units are calculated; S2, unit pressures and water contents are calculated, and the control volumes of each unit and between the units are corrected in real time; S3, initial control reserves and corrected control reserves are calculated according to the initial control volumes and the corrected control volumes, so that the remaining reserves and the remaining reserves distribution of the gas reservoir are determined. The application corrects the control volumes of each unit and between the units on the basis of the measured water content data of the gas well and the single-well testing interpretation result data, and on the basis of the gas reservoir engineering method and the intelligent optimization algorithm, so that the remaining reserves and the remaining reserves distribution of the water-bearing gas reservoir are determined, and the technical problem that the remaining reserves recovery efficiency cannot be improved because the natural gas is sealed by the water invasion in the water-bearing gas reservoir, and the sealed natural gas cannot be accurately identified is solved.

The embodiment of the present application discloses a kind of prediction reserve upgrade evaluation method and device based on exploratory well test oil production prediction.Therein, the prediction reserve upgrade evaluation method based on exploratory well test oil production prediction includes: determining the reservoir type in the block to be evaluated prediction reserve based on the obtained data;Collect the exploration data of the determined reservoir type;Based on the exploration data, establish the exploratory well test oil production prediction model corresponding to the reservoir type;Determine the plane distribution of parameters in the prediction model;Based on the plane distribution and prediction model, determine the upgrade prediction reserve range;Based on the upgrade prediction reserve range, obtain the reserve scale in the upgrade range.Using the exploratory well data of the same or similar reservoir type as the block to be evaluated prediction reserve, effectively solve the problem of lack of exploration data in the block to be evaluated reserve, achieve the purpose of quantitative prediction of exploratory well test oil production, avoid single reliance on geological analysis to evaluate the upgradability of prediction reserve.

The invention provides a crack parameter joint inversion method based on regional multi-well constraint. According to the method, on the basis of well test response of multiple wells in a target block, an inter-well weight relation is constructed by utilizing inter-well space distance and structure consistency information, and a joint inversion model containing a single well fitting item, a region consistency constraint item and a prior constraint item is established on the basis. Through a double-layer iteration structure formed by inner layer single well parameter optimization and outer layer area coordination updating, while single well test fitting precision is ensured, area consistency constraint is applied to key crack parameters, inter-well parameter interpretation differences are gradually weakened, and a stable and convergent multi-well collaborative inversion result is obtained. Compared with a traditional single well independent interpretation method, the method has the advantages that discreteness and multiplicity of an inversion result can be reduced, continuous and coordinated expression of fracture parameters on the regional scale is formed, and the method can be used for multi-well test comprehensive interpretation, fracturing effect evaluation and regional fracture parameter characterization under the complex reservoir condition.

The invention discloses a method for identifying a carbon dioxide leading edge position of carbon dioxide pre-fracturing through high-frequency pressure, and the method comprises the following steps: collecting carbon dioxide pre-fracturing high-frequency pressure data at a well bottom, and carrying out the nondimensionalization of the pressure data; determining inner and outer areas of the composite oil reservoir according to a well testing theory, and calculating mobility and mobility ratio; determining a dimensionless pressure equation and a definite solution condition according to stratum conditions, obtaining a bottom hole pressure expression, and performing inversion to obtain a numerical relationship with dimensionless combination time to make a typical oil line; the curve form is analyzed, and the stratum parameter influence is determined; and determining a carbon dioxide leading edge position. On the basis of a well testing theory and accurate pressure equation derivation, the characteristics of the composite oil reservoir are fully considered, including factors such as fluidity and fluidity ratio of an inner area and an outer area, shaft storage and skin factors and the like, pressure distribution in the oil reservoir and the flowing state of carbon dioxide can be more accurately described through mathematical modeling and analysis, and the analysis accuracy is improved. Therefore, the front edge position of the carbon dioxide can be determined more accurately.

This application provides a method and equipment for determining the final recoverable reserves of a fractured horizontal well in a tight reservoir. The method includes: establishing a well test model of the tight reservoir considering heterogeneity, stress sensitivity, and weak recharge effects; based on this well test model, using an analysis method derived from historical production data and the relationship between production-standardized pseudo-pressure and time, inverting and determining the fracture parameters of the horizontal well; calculating linear flow parameters based on the fracture parameters; and finally, simulating and calculating the final recoverable reserves of the fractured horizontal well in the tight reservoir based on the linear flow parameters. This application increases the accuracy of the predicted final recoverable reserves and reduces the prediction error by inverting and determining the fracture parameters of the horizontal well and calculating the linear flow parameters and final recoverable reserves based on the inverted parameters.

The invention provides a method and a system for evaluating a single-section well test based on a discrete fracture network technology. The method comprises the following steps: classifying fractures according to morphological characteristics of a fracture network; constructing a corresponding single-section well test interpretation model and a single-section well test mathematical model based on crack classification by using a discrete crack network technology; respectively inputting the well testing key parameters of each crack classification into a single-section well testing mathematical model, and drawing a single-section double logarithmic well testing curve of each crack classification based on a solving result; and analyzing the single-section double logarithmic well testing curve to obtain an evaluation conclusion of single-section well testing. According to the method, a discrete fracture model (DFN) is adopted for coupling matrix-fracture seepage, and the actual fracturing effect of the deep shale gas well and the complex degree of the fracture network are considered, so that the seepage characteristics of the complex fracture network are accurately represented; the influence of key parameters such as reservoirs and cracks on well test interpretation results is determined by establishing a single-section well test mathematical model, and the accuracy and reliability of well test fracturing effect evaluation under different crack classifications are improved.

The invention discloses a method and a device for simplifying a numerical well testing geological model of a fracture-vug type oil and gas reservoir. The method comprises the steps that according to the radius of a karst cave in the fracture-vug type oil and gas reservoir and the distance between the karst cave and a test well, the bottom hole pressure derivative sinking amplitude caused by the karst cave is determined according to the corresponding relation between the bottom hole pressure derivative sinking amplitude caused by the karst cave and the corresponding relation between the karst cave radius and the distance between the karst cave and the test well; the sinking amplitude of the bottom hole pressure derivative is the sinking amplitude of the lowest point in a double logarithmic curve of the bottom hole pressure derivative and time relative to a set bottom hole pressure derivative baseline; and in the process of establishing the numerical well testing geologic model of the well testing, deleting the karst cave of which the sinking amplitude caused by the bottom hole pressure derivative is smaller than a set sinking amplitude threshold value. According to the method, the concept of the sinking amplitude of the bottom hole pressure derivative caused by the karst caves is innovatively defined, the karst caves are screened on the basis of the concept, and reasonable simplification of the numerical well testing geologic model of the fracture-vug type oil and gas reservoir is achieved.

The invention belongs to the technical field of oil reservoir development dynamic monitoring data interpretation and analysis, and particularly relates to a well testing analysis and interpretation method for a single-medium different-boundary oil reservoir inclined shaft. A well testing analysis and interpretation method for a single-medium different-boundary oil reservoir inclined shaft comprises the following steps that according to the characteristics of a single-medium oil reservoir, an instantaneous point source diffusion equation of the single-medium oil reservoir is listed in combination with different types of boundary conditions; according to a mirror image reflection rule, carrying out infinite multiple times of symmetry along top and bottom boundaries through a LordKelvin basic solution, and superposing sources to obtain a single-medium oil reservoir instantaneous point source function basic solution under different types of boundary conditions; and integrating along the track of the mirror image inclined shaft in combination with the track of the mirror image inclined shaft, and obtaining the bottom hole pressure response of the inclined shaft in the single medium oil reservoir under different types of boundary conditions through dimensionless. Compared with a conventional vertical shaft theory for explaining inclined shaft data, the method has the advantage that the adaptability and precision of analysis and explanation can be greatly improved.

This invention belongs to the field of petroleum development technology, specifically disclosing a method, apparatus, equipment, and medium for waterflooding front characterization. It includes the following steps: acquiring production well test data and calculating the daily water injection volume for each layer; selecting different water injection wells as centers, and dividing the selected water injection wells according to the daily water injection volume for each layer, calculating the water injection volume divided from each water injection well towards each oil well; taking the water-flooded oil well as the center, acquiring the water injection volume divided from all water injection wells around the water-flooded oil well towards the water-flooded oil well, and determining the incoming water direction based on the magnitude of the water injection volume divided from different water injection wells towards the water-flooded oil well; acquiring actual oil well parameters to establish a volumetric model and calculate the waterflooding front area; characterizing the waterflooding front based on the waterflooding front area and the incoming water direction. This invention obtains accurate data by finely dividing the water injection volume, and calculates the waterflooding front area through a volumetric model, ensuring that the waterflooding front characterization result coincides with actual production, thereby improving production efficiency.

The application provides a salt deposition well test productivity evaluation method, device, system and storage medium, and belongs to the field of oil and gas development. The method comprises the following steps: introducing environmental parameters, water component parameters, natural gas parameters and salt component parameters, calculating the to-be-processed gas phase parameters through the environmental parameters, the water component parameters and the natural gas parameters; and obtaining the salt deposition amount per pore volume through salt content analysis of the water component parameters, the environmental parameters, the natural gas parameters, the salt component parameters and the to-be-processed gas-liquid phase parameters. Compared with a conventional well test analysis method, the application fully considers the influence of salt deposition on reservoir physical properties and fluid properties, improves the applicability to salt deposition gas wells, can be applied to productivity evaluation and prediction of salt deposition gas wells, and provides a basis for reasonable productivity evaluation and production system measure adjustment of gas wells.

This invention belongs to the field of new energy development technology. It discloses a control method and system for maintaining reinjection throughout the entire lifecycle of sandstone geothermal wells. The method includes: extracting continuous core samples and obtaining reservoir property data to establish a set of characteristic parameters for sandstone reservoirs; conducting reinjection condition simulation tests to obtain an optimal combination of parameters for the wellbore filtration structure; performing pumping and reinjection tests on the target geothermal well based on the optimal combination of parameters to determine initial reinjection parameters; acquiring chemical and microbial component data to determine the formation law of blockage substances under different reinjection flow rates, reinjection water temperatures, and system tightness conditions, and screening out an optimal combination of reinjection process parameters; implementing well washing operations; performing reinjection capacity retesting after well washing; comparing the retest results with the initial reinjection parameters; and dynamically adjusting the optimal combination of reinjection process parameters based on the comparison results. This significantly improves the service life of sandstone geothermal wells.

The application discloses a method for determining a static reserve threshold value of a faulted-dissolved body reservoir, an electronic device and a medium. The method can comprise: obtaining an actual well test interpretation curve according to well test monitoring data; establishing a well test curve theoretical chart of different threshold values through seismic carving; and comparing and analyzing the well test curve theoretical chart of different threshold values and the actual well test interpretation curve respectively, so as to take the threshold value corresponding to the well test curve with the highest fitting accuracy as an accurate threshold value. The application determines a seismic attribute threshold value in a static reserve calculation process of a faulted-dissolved body reservoir by using numerical well test means based on pressure recovery well test monitoring data, effectively eliminates the influence of working systems, production rates and other factors on the seismic threshold value, reduces the uncertainty of the static reserve calculation of the faulted-dissolved body reservoir, and consolidates the theoretical basis of the reserve calculation of the faulted-dissolved body reservoir.

The invention discloses an ultra-low permeability reservoir well test dynamic early warning method based on a water injection well and a related device. The method comprises the following steps: acquiring pressure drop speed data of the water injection well; detecting the ultra-low permeability reservoir water drive radius and judging stratum seepage characteristics and reservoir dominant channels by utilizing the obtained water injection well pressure drop speed data and well testing software; and presetting an oil production well exploitation safety standard, and based on the model change in the well testing software, pre-warning whether the stratum flow conductivity meets the oil production well exploitation safety standard or not. The water injection strategy and parameters can be adjusted in time by monitoring the pressure drop speed of the water injection well in real time and analyzing the water drive radius and the stratum seepage characteristics in combination with well testing software; secondly, the mining safety standard of the oil production well is preset, and based on the early warning function of well testing software, potential safety hazards such as insufficient stratum flow conductivity can be found in time.

This invention relates to the field of unconventional oil and gas reservoir development and artificial intelligence inversion technology. It discloses a method for inverting fracture network parameters by integrating well testing and microseismic data, addressing the problems of high computational cost and severe non-uniqueness in traditional numerical well testing inversion. This method constructs a well testing forward model and inversion sample library, completes data preprocessing, builds a training attention-enhanced operator learning surrogate model, and efficiently solves for pressure transient responses. It inverts global reservoir seepage parameters through multi-starting-point gradient descent, and constructs a probabilistic inversion model combined with microseismic constraints to accurately determine the half-length of segmented fractures. It relies on latent variable neighborhood search to screen effective solutions, quantifies parameter uncertainty, and outputs the results. This invention integrates well testing dynamics and microseismic monitoring data, improving inversion accuracy and rationality, enabling rapid well testing interpretation and parameter probabilistic evaluation, and is suitable for field development applications in shale oil fractured horizontal wells.