47 results about "Water development" patented technology

The application provides a low-grade oil reservoir water injection development effect evaluation method, comprising the following steps: S1, collecting core scale limit oil displacement efficiency data; S2, collecting well pattern controlled reserve degree data; S3, calculating sweep efficiency of the low-grade water drive oil reservoir; S4, correcting the sweep efficiency according to the changes of reservoir physical property parameters caused by near-well pollution and reservoir energy decline; and S5, calculating the reference recovery rate and evaluating the development effect. The application can effectively avoid collecting and arranging a large number of cumbersome production dynamic data, fully utilize the flow characteristics and dynamic physical property parameter evolution of the low-grade oil reservoir, accurately evaluate the development effect of the low-grade oil reservoir, and be beneficial to efficient development of the low-grade oil reservoir.

The invention discloses a multilayer heterogeneous oil reservoir water injection development balanced production well completion perforation optimization method, and relates to the technical field of oil and gas field development engineering. The method comprises the steps that S1, basic parameters of a multilayer oil reservoir are collected, and engineering constraints are determined; s2, performing numerical simulation on perforation near-well flow of the multi-layer oil reservoir based on basic parameters of the multi-layer oil reservoir and the engineering constraint, and establishing a skin coefficient inversion library; s3, a preset skin coefficient of each layer in the multi-layer oil reservoir is set, and water injection rate distribution of each layer of the multi-layer oil reservoir under the general water injection condition is calculated based on the preset skin coefficient; s4, on the basis of the water injection amount distribution, calculating the water drive leading edge advancing speed of the oil phase and the water phase; s5, on the basis of the water drive front edge advancing speed of each layer, the water drive front edge advancing speed variance of each layer in the multi-layer oil reservoir is determined; and S6, the steps S3-S5 are repeated, the preset skin coefficient set when the advancing speed variance of the water drive front edge of each layer is minimum is obtained, and the optimal perforation parameter combination at the moment is obtained.

The present application relates to the field of profile control and water plugging in oilfield water injection development, and discloses a polyacrylamide copolymer, a preparation method thereof, a profile control and flooding movable gel and application. The polyacrylamide copolymer contains a structural unit shown in formula (1), a structural unit shown in formula (2) and a structural unit shown in formula (3); wherein R is C4-C10 alkyl, n is an integer of 6-15, and M is a metal element; the profile control and flooding movable gel formed by the acrylamide copolymer can enter the deep part of an oil reservoir, has a relatively high viscosity under high-temperature and high-salt conditions, can reduce the oil-water surface interfacial tension, is suitable for being used as a profile control and flooding agent and a profile control and plugging agent in a high-permeability oil reservoir (permeability is higher than 2000 mD), has a relatively high plugging rate and has good emulsifying performance.

The invention relates to an edge-bottom water reservoir natural energy evaluation method, and belongs to the technical field of reservoir development. According to the edge-bottom water reservoir natural energy evaluation method, firstly, the rock pore compression coefficient is calculated, then the accumulated water invasion amount of the reservoir is calculated according to the geological parameters and the production and development parameters of the reservoir, and then the natural energy activity index of the reservoir is calculated. And finally, determining the natural energy activity degree of the oil reservoir according to the natural energy activity index. The edge-bottom water reservoir natural energy evaluation method is suitable for non-closed unsaturated water pressure driven reservoirs, namely the reservoirs which have connected water bodies and have the water invasion effect due to reservoir pressure drop in the exploitation process, is suitable for the reservoirs subjected to water injection development and natural energy production, and has high evaluation accuracy.

The application provides a method for realizing pressure head migration by using a front carbon dioxide slug to assist water injection, comprising the following steps: step 1, establishing a model of water injection assisted by a front carbon dioxide slug; step 2, calculating the required water injection volume for water injection according to a production scheme and reservoir production data, and combining a pressure distribution model to optimize the volume of the required carbon dioxide slug; step 3, injecting the carbon dioxide slug according to the calculation result of step 2 to realize pressure head migration; and step 4, after the carbon dioxide slug is injected, water injection development is carried out in the way of water injection to form a development model of water and carbon dioxide slug oil displacement. The method for realizing pressure head migration by using a front carbon dioxide slug to assist water injection combines the advantages of water injection and carbon dioxide displacement, achieves good oil displacement effect at a low cost, and has a great application prospect in the development of low-permeability reservoirs, tight reservoirs and fault block reservoirs.

The invention belongs to the technical field of dynamic monitoring of oil production engineering, and particularly relates to a method for analyzing and identifying inter-well connectivity based on microbial genome DNA (Deoxyribose Nucleic Acid). Comprising the following steps: acquiring liquid samples of a producing well and a water injection well and rock debris samples of a new drilled well in the same area and the same stratum as the producing well; carrying out microbial genome DNA analysis on the obtained sample to obtain dominant strain compositions of the oil producing well, the water injection well and the newly-drilled well; comparing the number of the dominant strains shared by the producing well and the water injection well and the number of the dominant strains shared by the producing well and the new drilling well, and judging the connectivity of the producing well and the water injection well according to a comparison result. The invention provides a novel inter-well connectivity identification method, which can effectively solve the problems that the water breakthrough direction of an oil production well is complicated and is difficult to identify clearly due to the influence of dominant channels, natural fractures, water injection dynamic fractures and other factors on a water injection development oil reservoir.

The application discloses a hydrate secondary generation prevention and treatment system and method for combustible ice collection pipeline, which comprises a gas phase collection pipeline for conveying output gas phase medium and a liquid phase collection pipeline for conveying output liquid phase medium, the liquid phase collection pipeline is connected with a liquid phase pipeline hydrate control system for separating free gas of wellhead liquid phase produced medium. Based on the theory of sea area combustible ice mining, the application conforms to the depressurization mining mode, aims at the medium characteristics of the gas phase channel and the liquid phase channel output during the underground decomposition, combines the pressure and temperature conditions under the deep water development environment, evaluates and obtains the viewpoint that the hydrate secondary generation risk of the gas phase medium collection pipeline is smaller under the basic maintenance of 3MPa operating pressure, and the liquid phase medium collection pipeline is mainly prevented from the hydrate secondary generation, and the gas-liquid secondary separation scheme is provided to prevent the hydrate secondary generation of the liquid phase medium collection pipeline from the components.

The application discloses a carbonate reservoir water injection development prediction method and system based on a dual-domain neural operator, relates to the technical field of carbonate reservoir water injection development prediction, and comprises the following steps: obtaining an original input tensor from a reservoir reservoir space model; extracting low-frequency global features and high-frequency local features of the original input tensor from a high-dimensional feature space through a dual-domain feature extraction framework; performing adaptive fusion weight calculation based on an energy range, fusing the low-frequency global features and the high-frequency local features according to the calculated fusion weight, and obtaining fused features; processing the fused features through a feature decoding layer, outputting the processing result of the fused features through an output layer, and obtaining a numerical simulation result of the carbonate reservoir; obtaining a development prediction yield of the carbonate reservoir according to the numerical simulation result; and fundamentally solving the technical problem that the precision and efficiency of the prior art are difficult to balance under extreme heterogeneous conditions.

This invention discloses a method for adjusting reservoir development layers and well patterns, as well as a method for developing carbonate reservoirs. The method for adjusting reservoir development layers and well patterns includes: dividing the reservoir into Class I and Class II reservoirs according to a set classification standard, with Class I reservoirs exhibiting better permeability and homogeneity than Class II reservoirs; splitting the vertical well reverse nine-spot well pattern used for reservoir development into two sets of five-spot well patterns, and separately performing stratified water injection development on Class I and Class II reservoirs until the first predetermined stage; combining the two sets of five-spot well patterns into a new reverse nine-spot well pattern, and using the new reverse nine-spot well pattern for water injection development on Class I reservoirs. This method differentiates the well pattern configuration based on the different physical properties and reserve utilization difficulties of different types of reservoirs, achieving stratified water injection for oil production and solving problems such as single-layer breakthrough, large differences in vertical water drive effects, low reserve utilization, and severe ineffective water circulation. It maximizes the adjustment and rational utilization of old well patterns, reduces drilling and completion investment, and is highly operable.

The present application relates to a kind of multilayer series oil reservoir water injection development layer series reorganization method, obtains well bottom flow pressure when oil layer is separately produced;Pressure loss of fluid is calculated from lower oil layer position to upper oil layer position;Well bottom flow pressure pressure difference between lower oil layer and upper oil layer is compared with pressure loss, the production pressure difference when oil layer is separately produced is corrected to the production pressure difference when two layers are combined, and then the corrected well bottom flow pressure is obtained;Each oil layer flow and total flow are calculated by the corrected well bottom flow pressure;Total flow and the relationship chart of different flow coefficient ratio under combined production vertical distance are drawn;Flow loss amplitude limit is determined according to the minimum oil layer distance and economic benefit, and combined production limit flow is obtained;According to the relationship chart of total flow and different flow coefficient ratio under combined production vertical distance and combined production limit flow, flow coefficient ratio and combined production vertical distance limit relationship chart are determined, whether lower oil layer and upper oil layer can be combined is determined, and the present application provides theoretical basis and guidance.

The present application relates to the technical field of oil production engineering, and particularly relates to a numerical simulation method for extra-low permeability reservoirs, comprising: sequentially determining the relationship between apparent permeability and throat size, the relationship between apparent permeability and air permeability, and the relationship between the radius of the bulk phase fluid and the pressure gradient, to obtain the relationship between permeability and apparent permeability under the condition of a definite solution; correction of oil-water relative permeability; water injection development is carried out by using a reverse nine-spot well pattern, and simulation is carried out by using Darcy seepage and low-speed non-Darcy equivalent seepage respectively with a month as a time step; fixed liquid production is carried out, and the indicators of the whole region are fitted. The present application analyzes and compares Darcy seepage and non-Darcy seepage by using the numerical simulation method for extra-low permeability reservoirs, obtains the seepage characteristics of the extra-low permeability reservoirs, and provides a guiding role for exploitation and other work.

The invention discloses a carbonate reservoir water-flooding development prediction method and system based on a double-domain neural operator, and relates to the technical field of carbonate reservoir water-flooding development prediction.The method comprises the steps that an original input tensor is obtained from a reservoir space model; low-frequency global features and high-frequency local features of the original input tensor are extracted from the high-dimensional feature space through a double-domain feature extraction framework; self-adaptive fusion weight calculation is carried out based on the energy range, the low-frequency global features and the high-frequency local features are fused according to the fusion weight obtained through calculation, and fusion features are obtained; the fusion features are processed through a feature decoding layer, the processing result of the fusion features is output through an output layer, and a numerical simulation result of the carbonate reservoir is obtained; obtaining the development prediction yield of the carbonate reservoir according to a numerical simulation result; the technical problem that the precision and the efficiency are difficult to consider under the extreme heterogeneous condition in the prior art is fundamentally solved.

The application provides a high water cut stage reservoir variable flow line regulation method based on a triangular phase diagram, which comprises the following steps: step 1, evaluating the dispersion degree of remaining oil; step 2, using the result of logarithmic processing of the instantaneous liquid passing multiple to represent the hydrodynamic strength; step 3, calculating the dominant potential abundance as a representation index of reservoir potential; and step 4, classifying the reservoir flow line parameters through a density peak value algorithm to establish a flow line adjustment technology partition. The high water cut stage reservoir variable flow line regulation method based on the triangular phase diagram is simple, quick and effective, easy to use and popularize, and can better guide the remaining oil tapping work in the high water cut development stage of the reservoir, and plays an important economic benefit in improving the recovery efficiency and improving the development effect of the old oilfield.

The present disclosure relates to a method for determining the amount of profile control agent for low-permeability water injection development oil field, and provides a method model for calculating the amount of profile control agent for low-permeability water injection development oil field. The model first considers factors such as stress sensitivity, variable starting pressure gradient, and irregular well pattern form, and can accurately calculate the required amount of profile control agent for different well groups in each target layer. The calculation result of the amount of profile control agent has a small gap with the field, thereby providing a basis and guidance for development adjustment parameter optimization. Because the amount of profile control agent for well groups can be calculated by using the method, a theoretical basis can be provided for water injection parameter optimization and water injection adjustment, and effective guidance can be provided for oil field development adjustment, thereby providing technical support for treating low-efficiency and ineffective circulation, and ultimately achieving the purpose of improving water injection development effect and benefit.

The invention relates to the technical field of reservoir numerical simulation application, in particular to a post-water-drive flow field evaluation method and device for water-drive development of a low-permeability volatile reservoir. The method comprises the following steps: determining a moisture flow field in a grid according to fluid parameters and grid thickness in the grid corresponding to an oil reservoir geologic model of a target low-permeability volatile oil reservoir; determining a residual reserve abundance field in the grid according to the fluid parameters and the saturation in the grid; determining a displacement intensity field in the grid according to the fluid parameters and the water flows in different directions in the grid; and according to the water flow field, the residual reserve abundance field and the displacement intensity field, evaluating the post-water-flooding flow field of the low-permeability volatile oil reservoir. The invention provides a whole set of scientific, reasonable and widely applicable grading evaluation method for characterizing and evaluating the seepage flow field of the water development low-permeability volatile reservoir.

The invention relates to an energy storage refracturing process parameter design method for an integral block. The method comprises the following steps: S1, acquiring basic data of the integral block; s2, determining geological main control factors influencing the productivity according to the reservoir physical property data; s3, establishing a reservoir geologic model by using the basic data in the step S1, and dividing different reservoir types by using geologic main control factors; s4, for each reservoir type, a nine-point water injection development well group is selected, and the optimal water drive front position is determined; and S5, according to the optimal water drive front edge position in the step S4, fracturing parameters are optimized by taking well group productivity as a target. According to the method, the problem that water injection energy storage parameter and hydraulic fracturing parameter optimization methods are lacked in the energy storage and refracturing process of the whole block of the low-permeability reservoir is solved, the pertinence is higher, and refined optimization of different types of reservoirs of the whole block is achieved.

The application discloses a method and system for determining a reasonable water drive lower limit of horizontal well development in an ultra-low permeability reservoir, and belongs to the field of oilfield development. By obtaining the throat radius, the direct factor of restricting the fluid flow capacity, the reservoir percolation capacity can be better reflected; the higher the proportion of the number of fractures in the non-safe range, the greater the risk of water breakthrough in the fractured reservoir, and the less favorable the water injection development effect; the proportion of the water breakthrough oil production well can determine the adaptability of water injection development; according to the obtained yield, water injection development can be adopted when the yield is greater than 1; according to the average throat radius membership function, the number of fractures in the non-safe range membership function, the water breakthrough oil production well proportion membership function and the economic benefit membership function, the reservoir evaluation coefficient is obtained; when the reservoir evaluation coefficient is greater than the set value, the reservoir is suitable for horizontal well water injection development; when the reservoir evaluation coefficient is less than the set value, the reservoir is not suitable for horizontal well water injection development, and the horizontal well development mode of the ultra-low permeability reservoir can be determined.

The application discloses a kind of intelligent injection well control systems and methods with anti-backout function, it is related to oilfield water injection development technical field, the application includes: data acquisition module, data analysis module, data processing module and local database, through wired pressure transmitter accurate collection injection well dry pressure, oil pressure data, constructs pressure monitoring data set by data correlation, realizes the quick determination and automatic protection of backout risk by pressure value comparison, and continuously monitors pressure change, by difference calculation and analysis backout risk removal condition and restore normal injection, whole system relies on remote terminal unit RTU and realizes integrated intelligent control, pressure monitoring hardware type, range and preset recovery threshold value etc. can be flexibly configured as needed, can accurately prevent and control backout risk, protect pipe network and precision instrument, adapt to various injection well field conditions, improve the intelligentization, stability and operation efficiency of oilfield water injection development.

The embodiment of the invention relates to a method and device for determining a liquid extraction scheme of a water-flooding oil field, and the method comprises the steps: drawing a curve of formation pressure and liquid production capacity corresponding to at least one target oil production well bottom flow pressure value under the target water content of a target block, and forming a production capacity net diagram; forming an injection quantity net diagram according to the curve of the formation pressure and the injection quantity corresponding to the bottomhole flowing pressure value of the at least one target water injection well; the two mesh diagrams are intersected and coupled to form a liquid extraction scheme optimal layout which takes the original formation pressure as the upper limit value of the formation pressure, the saturation pressure as the lower limit value of the formation pressure, the first preset value as the lower limit value of the flowing bottomhole pressure of the producing well and the second preset value as the constraint condition of the upper limit value of the flowing bottomhole pressure of the water injection well and meets the injection-production dynamic balance condition; according to the extraction scheme optimization layout, a target extraction scheme of the water-flooding oil field is determined, an extraction scheme optimization layout of injection-production dynamic balance under the control of injection-production pressure is constructed, and a visual basis is provided for optimization of the extraction scheme of the water-flooding oil field.

The utility model relates to a kind of semi-open cylinder fish finding and collecting device, belong to the technical field of fish finding and collecting in well operation, including connecting head, introduction centralizer section and half-split guide section, connecting head is sequentially connected with introduction centralizer section, half-split guide section.This application develops semi-open cylinder fish finding and collecting device, after failure of casing milling management, the device is used to carry out fish finding and collecting construction to casing broken well, the device uses the characteristics of semi-open cylinder, rotates the fish finding pipe column with open pipe, and the fish top is collected into open pipe, the fish top is trimmed in fish finding pipe column, by replacing damaged casing, completely eliminate casing broken well safety environmental protection hidden danger, protect normal water injection development in block.

The present application provides a method for improving the recovery of fault block reservoir by water injection, which comprises the following steps: step 1, selecting a target area, the selection principles including fault block sealing property, necessity of water injection and well condition of oil and water wells; step 2, determining water injection parameters, including water injection well, water injection amount in water injection cycle, water injection speed, water injection pressure, water injection mode and well shut-in cycle; step 3, determining the well opening strategy after water injection, including well opening sequence of oil wells and working system after well opening. The method for improving the recovery of fault block reservoir by water injection has important significance for the development effect of water drive fault block reservoir, and finds a new direction for the recovery enhancement technology of water drive reservoir.

The invention discloses a water injection well acidification method, system, equipment and medium, and belongs to the technical field of oilfield water injection development. The water injection well acidification method comprises the following steps that the real-time water absorption index change rate is obtained; the real-time water absorption index change rate is compared with a water absorption index change rate threshold value, and whether acidification operation is needed or not is judged; when the real-time water absorption index change rate is larger than a water absorption index change rate threshold value, acidification operation is carried out, and when the real-time water absorption index change rate is smaller than or equal to 0, acidification operation is stopped. According to the method, the water absorption condition of the water injection well is analyzed in real time through the water absorption index change rate, and the starting and stopping opportunities of acidification operation are decided according to the change of the water absorption condition.

This invention relates to the field of oilfield water injection development technology, specifically a method, apparatus, electronic equipment, and storage medium for determining effective production wells in conventional sandstone water injection oilfields. The method involves inputting the water drive radius of the injection well, the coordinates of the injection well, the drainage radius of the production well, the coordinates of the production well, and the distance between the oil and water wells into effectiveness judgment conditions. A production well meeting all these conditions is considered an effective well. These conditions include: the distance between the oil and water wells is less than the sum of the water drive radius of the injection well and the drainage radius of the production well; the oil and water wells do not intersect with faults (the oil and water wells include both the injection well and a production well); and there are no intersections between the oil and water wells and any boundaries of the sand body (the oil and water wells include both the injection well and a production well). This invention can automatically determine one or more effective production wells from a pool of production wells, thereby automatically determining the injection-production well group. Compared to the traditional method of manually dividing injection-production well groups, this method is time-saving, labor-saving, efficient, and highly accurate.

The invention relates to the technical field of oilfield water injection development, in particular to a hydraulic dredging and cleaning method in a shaft. According to the method for hydraulic dredging and cleaning in the shaft, after target well parameters are obtained through well logging work, the water outlet speed of a jet hole is calculated, then dirt types of the inner wall of the shaft are divided, the ultimate strength of the dirt types is calculated, the pressure of a water pump is calculated according to the ultimate strength, and meanwhile the radius of a flushing oil pipe during sand flushing is calculated; and finally, adjusting on-site well washing equipment according to a calculation result. According to the method for hydraulic dredging and cleaning in the shaft, the dirt types are divided and the ultimate strength is calculated after the outlet flow speed of the hydraulic jet hole is calculated, the underground dirt is analyzed, and the equipment parameters for removing the dirt are calculated, so that the success rate of underground treatment work is improved, and meanwhile, the work of lifting a pipe column is not needed; and the working period is shortened, and the working cost is reduced.

The invention relates to an ultra-low permeability reservoir water drive displacement boundary calculation method. The method comprises the steps that S1, the permeability K of a plurality of rock cores is obtained; s2, establishing a conversion model of core nuclear magnetic resonance relaxation time and pore throat radius r; s3, according to the pore throat radius r and the cumulative distribution frequency thereof, calculating the average pore throat radius of the rock core and a variable coefficient Dr; s4, acquiring displacement boundaries of a plurality of rock cores; and S5, establishing a core displacement boundary mathematical model, and calculating the displacement boundary of the ultra-low permeability reservoir water-flooding development through the model. According to the characteristics of the ultra-low permeability reservoir, the displacement boundary model is established by integrating the macroscopic physical property parameters and the microcosmic pore throat characteristic parameters, the displacement boundary of ultra-low permeability reservoir water drive development can be effectively predicted, selection of ultra-low permeability reservoir development modes is effectively guided, and ultra-low permeability reservoir scale benefit development is supported.

The invention discloses a shaft single-phase fluid flow prediction method and system based on a noise spectrum, and the method comprises the steps: deducing and building a relation model between flow and noise amplitude based on the incidence relation between noise and flow in a single-phase fluid flowing process, and representing the relation between the flow and the noise amplitude through an optimal frequency band range; by calculating correlation coefficients of noise cumulative amplitudes and flow under different frequency band ranges, selecting a frequency band range corresponding to a maximum value condition of the correlation coefficients to obtain an optimal frequency band range; based on the determined optimal frequency band range, a determined relational expression of the flow and the noise amplitude is obtained, and the flow value of the shaft single-phase fluid is calculated according to the determined relational expression. According to the novel shaft single-phase fluid flow prediction method based on the noise spectrum, the calculated shaft single-phase fluid flow has the highest coincidence rate with actual shaft fluid distribution, and key technical support is provided for dynamic accurate evaluation of an unconventional oil and gas reservoir water injection development injection well and guidance of optimization and adjustment of an injection well scheme.

This application provides a method and apparatus for evaluating the dynamic connectivity between wells in water-injection development reservoirs, relating to the field of reservoir water-injection development technology. The method includes: establishing virtual well points within the reservoir area under lithofacies control; establishing virtual nodes representing edge water and / or bottom water; simplifying the reservoir area into several connecting units between reservoir well points, where reservoir well points include real wells, virtual well points, and virtual nodes; assigning characteristic parameters to the connecting units to obtain a dynamic connectivity model between reservoir wells; minimizing the error between the actual dynamic production indicators and the predicted dynamic production indicators of the reservoir area; updating the characteristic parameters of the connecting units to the characteristic parameters that minimize the error; and evaluating the inter-well connectivity relationship using the corrected dynamic connectivity model. As described above, by establishing a dynamic connectivity model between reservoir wells that better reflects real geological understanding, an efficient and accurate evaluation of the inter-well connectivity relationship is achieved.

The utility model discloses an oil field water injection development throttling water distribution device internally provided with a filtering unit, which relates to the technical field of oil field development and comprises a throttling valve and a filtering pipe, the filtering pipe is fixed on one side of the throttling valve, an operation box is fixed on one side of the filtering pipe, and a rotating shaft is rotatably connected in the operation box. Through the arrangement of the frame with the arc-shaped structure and the filter screen, fluid can be guided to flow along a curved surface, turbulent flow and flow separation are reduced, formation of a local high-speed area is avoided, the filter area can be increased, and the filter is more suitable for oilfield water injection scenes with high sand content and high suspended matter content; a motor is started to drive a half-tooth bevel gear to be in engaged connection with a first bevel gear and a second bevel gear in turn, so that reciprocating half rotation of a rotating shaft is achieved, and a scraper is driven to clean impurities on the surface of a filter screen.

The application provides a fracture reservoir imbibition production calculation method based on historical injection-production data, and belongs to the technical field of oilfield development, and comprises the following steps: step 1, collecting geological reservoir parameters of a target oilfield, dividing a calculation time step, and arranging injection-production historical data of each time step; step 2, calculating the average water saturation of a fracture system; step 3, calculating the water storage of the fracture system and the matrix system; step 4, calculating the cumulative oil production and daily oil production of the matrix system and the fracture system; step 5, calculating the recovery degree of the matrix system and the fracture system; and step 6, based on the calculation results of steps 4 and 5, evaluating the development effect of the oilfield. The method can quickly calculate the imbibition production and recovery degree of the fracture reservoir, provides technical support and theoretical guidance for formulating the development technical policy of the fracture reservoir, improves the development effect of the fracture oilfield, and is suitable for the fracture water injection development oilfield.

The invention relates to the technical field of oil exploitation, in particular to a microscopic oil displacement energy conversion analysis method. The method comprises the following steps: making a pore throat channel pattern into a glass microscopic model by using a wet etching method, performing a microfluidic displacement experiment by using the model, and recording result images of each displacement stage; identifying and acquiring a contact angle value distribution condition by utilizing an experimental result image in each displacement stage, and metering shape parameter values such as contour perimeter and the like of each remaining oil region; according to the contact angle identification and measurement result, the pore radius value corresponding to each remaining oil distribution area is obtained, the average radius is calculated, and the average capillary pressure is obtained and used for representing the microcosmic remaining oil starting pressure; and according to a definition formula of work, combining the contact angle value, the perimeter of the contour of the remaining oil area and the average capillary pressure to obtain the magnitude of work required for using the remaining oil at the corresponding position. The method provided by the invention effectively guides the actual water injection development of the oil field in the high-water-cut period, and realizes the improvement of the recovery degree of the remaining oil in the high-water-cut period.