127 results about "Water development" patented technology

The embodiment of the invention provides an injection-production scheme optimization method and system based on the dominant water flow direction between injection-production wells, and belongs to the technical field of complex oil reservoir development. The method comprises the following steps: collecting geological detection information and production state information in a target well group range to form fitting basic data, and preprocessing the fitting basic data; based on the preprocessed fitting basic data, reservoir geologic feature recognition and dynamic response feature recognition are executed respectively; executing main control factor identification based on the dominant water flow identification result; and generating a corresponding injection-production optimization scheme based on the identified main control factors, and pushing the injection-production optimization scheme to a user side. According to the scheme, the problems that in the prior art, dominant water flow direction judgment is not accurate, and an optimization scheme lacks pertinence are effectively solved, the water injection development effect is remarkably improved, resource allocation is optimized, and finally efficient utilization of reserves and maximization of the recovery ratio are achieved.

The invention discloses a rock hydraulics-based high-position separation water monitoring and drainage control method, which comprises the following steps of: determining a separation water development position according to an early-stage exploration result; a monitoring drill hole and a drainage drill hole which are communicated with the separation water are constructed on the ground surface above the development position of the separation water; a water pressure sensor is arranged at the bottom in the monitoring drill hole; a water suction pump is arranged in the drainage drill hole; a plurality of micro-seismic sensors are arranged in a roof rock stratum of the working face at set intervals, and the development height of the water flowing fractured zone is determined according to micro-seismic signals collected by the micro-seismic sensors; determining the thickness of a separation layer water-resisting layer according to the development height of the water flowing fractured zone; determining an abscission water warning water head according to the thickness of the abscission water water-resisting layer; determining a warning water level according to the separation water warning water head and the separation water bottom plate elevation obtained through early-stage exploration, and setting the determined separation water warning water level as an early warning water level; the water level data in the monitoring drill hole are collected in real time, the real-time water level is obtained, when the real-time water head exceeds the early warning water level, the water suction pump is started to pump separation water, and separation water level control is achieved.

The invention provides a method for predicting and controlling water injection pressure rise of a water injection well, which comprises the following steps of: 1, collecting data of the water injection well according to different characteristics of each stage of water injection development of an oil reservoir; 2, according to the water injection well data, water injection well dynamic analysis is conducted; 3, establishing a water injection well water injection pressure rise prediction model according to oil reservoir factors by taking the water injection pressure as response and the factors influencing the water injection pressure rise as variables; and 4, according to the water injection well water injection pressure rise prediction model, a water injection well pressure rise control method is formulated. According to the water injection well water injection pressure rise prediction and control method, the prediction model is established, the water injection well pressure rise trend is predicted according to the model, a targeted control method is formulated, advanced early warning is achieved, effective water injection is guaranteed, and the purposes of more water injection and good water injection are achieved.

The invention relates to a horizontal well water control mode and parameter optimization method, device, medium and equipment suitable for offshore oil reservoir water injection development, and the method comprises the following steps: obtaining a water control characteristic curve of each water control valve based on a fluid circulation test experiment, and fitting a pressure drop formula; through water-control-free reservoir numerical simulation, the daily production fluid profile and water content profile characteristics of a production well are obtained, and then a horizontal well water control packer section optimization scheme is determined; on the basis of a fitted pressure drop formula and a horizontal well water control sealing section optimization scheme, the pressure drops of the water control valve pieces are controlled to be at the same level, and the water control and oil increase effects of all the water control valve pieces are simulated; and according to the economic cost, the water control and oil increasing effects of all the water control valve pieces are compared, and the production well water control mode is determined. The method can improve the water control, well completion, oil increase and water control effects in actual production of the horizontal well.

The invention relates to a method for evaluating the oil production potential of an oil reservoir in an ultra-high water cut period, and belongs to the technical field of oil development. According to the method for evaluating the oil production potential of the oil reservoir in the extra-high water cut period, various parameters influencing the oil production capacity and the time-varying property of the permeability in the production process are comprehensively considered, the virtual well method is introduced to calculate the oil production of each grid, and oil production potential distribution diagrams of different areas are generated; therefore, the oil production capacity of oil reservoirs in different areas in the later stage of water drive development is quantitatively and visually represented, potential tapping scheme deployment is quantitatively guided, and the method has important guiding significance for fine development of ultra-high water-cut oil reservoirs. According to the method, various factors influencing the oil production capacity of the oil reservoir are comprehensively considered, and the problem that oil production potential description of remaining oil is not accurate enough is solved; meanwhile, the influence of the accumulated water injection rate of the water injection development oil reservoir in the extra-high water cut period on the permeability is considered, the permeability of the digital-analog model is updated and corrected through the relation between the water passing multiple and the permeability, and the precision of quantitative characterization of the oil reservoir numerical model and the oil production potential is improved.

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 provides a water burst and mud burst prediction method based on a comprehensive advanced geological forecast fault fracture zone, and relates to the technical field of geological disaster prediction, through a fault fracture zone existence possibility grade, an approaching precursor grade, a rock mass integrity degree grade, a drilling condition grade, a seismic wave reflection method grade and a geological radar method grade, the fault fracture zone existence possibility grade, the approaching precursor grade, the rock mass integrity degree grade, the drilling condition grade and the geological radar method grade are calculated; and predicting the scale grade of the fault fracture zone by using a polynomial naive Bayes-based fault fracture zone comprehensive prediction model so as to obtain the scale of the fault fracture zone, if the fault fracture zone does not exist, determining that water bursting and mud bursting do not exist, and if the fault fracture zone exists, determining that water bursting and mud bursting do not exist. And combining the water conductivity grade of the fault fracture zone, the rock mass integrity degree grade, the underground water development degree grade and the surface water supply condition grade, and utilizing a fault fracture zone water gushing and mud bursting grade prediction model based on a genetic algorithm and a support vector machine to predict the fault fracture zone water gushing and mud bursting grade. The problem that the water burst and mud burst grade of the fault fracture zone cannot be predicted in the prior art is solved.

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 present invention provides a method for evaluating the flow field adaptability of a high water cut reservoir. The method for evaluating the flow field adaptability of a high water cut reservoir includes: Step 1, establishing a numerical simulation model of the reservoir and obtaining evaluation parameters; Step 2, performing data preprocessing; Step 3, calculating the evaluation index for the flow field adaptability of a high water cut reservoir; Step 4, finding the optimal regulation plan for the reservoir. The method for evaluating the flow field adaptability of a high water cut reservoir can accurately understand the development laws and development status of oilfields in the ultra-high water cut development stage, propose a set of systematic evaluation indexes and evaluation criteria, establish an evaluation system, effectively determine whether the current development plan is reasonable, so as to find out the main factors restricting the development effect of the oilfield at this stage, and provide a basis for the development adjustment of the reservoir in the high water cut stage.

The invention discloses a multi-process combined fracturing transformation method for avoiding a water injection layer series, which comprises the following specific steps of: 1, comprehensively logging and logging to explain the condition of an oil-water layer and the characteristics of fracturing transformation, classifying and grading a horizontal section, and determining an engineering dessert; 2, differentiated cloth seam design is carried out according to the engineering dessert distribution in the step 1; step 3, determining design parameters of the horizontal well according to the position of the engineering dessert of the horizontal section and the seam distribution mode; 4, different types of perforation technologies are selected according to the design parameters in the step 3; 5, fracturing operation is conducted according to the perforation technology determined in the step 4; and step 6, monitoring the fracturing operation process in real time by adopting underground microseism, adjusting design parameters, and guiding fracturing construction. According to the fracturing transformation method for avoiding the water injection layer series through the multi-process combination, the design parameters of the horizontal well are adjusted, different perforation technologies are selected for fracturing operation, and communication of the water injection development layer series or the water drive front edge is effectively avoided.

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 invention provides an underground profile control and water injection integrated tool, and belongs to the technical field of oilfield water injection. By integrating the upper connector, the lower connector, the central overflowing channel, the main board assembly, the flow adjusting assembly, the ultrasonic circuit measuring assembly, the ultrasonic probe assembly and the outer protection pipe and cooperating with a communication cable, remote monitoring and measuring and adjusting under normal water injection of one pipe column can be achieved, and efficient injection of various profile control agents (including large particles, large viscosity and the like) can be achieved; the method can effectively solve the problems of complex operation, low efficiency, high construction cost and the like of the existing process, and provides powerful technical support for low-cost and efficient water injection development of high-water-cut-period oil reservoirs.

The invention discloses a deep sea water development work ship which comprises a ship body and a water taking system. Specifically, the water taking system comprises a transfer device, a lifting device and a plurality of cold water pipe joints, the transfer device is installed on a ship body, the lifting device comprises a hoisting mechanism, a pipe joint lifting tower and a seawater lifting pump, the hoisting mechanism and the pipe joint lifting tower are movably installed on the ship body, and the cold water pipe joints are stored in the transfer device. The multiple cold water pipe joints can be movably spliced in the height direction, each cold water pipe joint is provided with a heat insulation layer, the pipe joint lifting tower is used for moving the cold water pipe joints between the transfer device and the hoisting mechanism and splicing the multiple cold water pipe joints to form a cold water pipe column, and the hoisting mechanism is used for lowering and lifting the cold water pipe column. The seawater lifting pump is used for pumping deep sea water to the ship body through the cold water pipe column. Therefore, the temperature stability of the deep sea water can be improved, and development and utilization of the deep sea water are facilitated. The method is widely applied to the technical field of deep sea water development.

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 invention relates to a reinjection water injection capacity evaluation method, evaluation device, equipment and medium, in particular to the technical field of oilfield water injection development, based on the fact that a dimensionless water absorption index is reduced along with increase of the reinjection proportion of reinjection water in injected water, quantitative characterization is conducted on the reinjection water through index decreasing, and the reinjection capacity of the reinjection water is evaluated. And the change relation between the water absorption index of the water injection well and the water content of the oil field can be deduced. In addition, according to the relative permeability curve, the change relation of the fluid production index of the production well along with the water content of the oil field can be obtained. And calculating the change relation of the maximum water injection speed and the maximum liquid production speed of the well network unit along with the water content in combination with the water absorption index and the liquid production index tested in the oilfield exploration evaluation stage or the initial development stage, and evaluating the injection capability risks in different water-containing stages by comparing the difference between the two. The evaluation method provided by the invention not only can quantitatively evaluate the yield reduction risk caused by the reduction of the injection capability through a theoretical method, but also can be applied to numerical simulation, and has wide applicability.

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 fractured shale gas reservoir gas-water self-absorption prediction model and method, and the method comprises the following steps: S1, obtaining a core sample of a target reservoir, drying the core sample, and obtaining the basic physical property parameters of the core sample; s2, simulating gas-water self-absorption by adopting the rock core sample to obtain sucked water volumes and contact surface areas at different moments; s3, establishing a fractured shale gas reservoir gas-water self-absorption prediction model, and fitting according to a result of the step S2 to obtain a fitting coefficient of the prediction model; and S4, according to the prediction model after the fitting coefficient is determined, predicting the water absorption capacity and the water absorption rate of the target reservoir in the unit contact area under different water absorption time. According to the method, the water absorption capacity and the water absorption rate of the fractured shale gas well in the water injection development process can be accurately predicted and obtained only through the basic physical property parameters of the rock core.

The present invention provides a method for fine characterization and evaluation of oil sand bodies based on multi-information fusion. The method comprehensively considers multiple information such as drilling, logging, production dynamics, and seismic information, identifies and divides single sand bodies based on sedimentary feature analysis, understands the correspondence between sand bodies and sedimentary change laws based on multiple information, and compares single sand bodies. The method uses well information and seismic technology to depict sand body microstructures, comprehensively judges reservoir boundaries and oil layer boundaries based on multiple information, marks the top elevation depth of a single sand layer, oil layer thickness, and sand layer thickness beside the well, comprehensively evaluates the oil and water layers encountered in drilling at different water injection development stages, judges the distribution law of oil sand bodies, standardizes the compilation of oil sand body maps, and accurately evaluates oil sand bodies. The method provides an important geological basis for the compilation of oilfield development plans, and improves the accuracy and reliability of remaining oil evaluation.

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 invention relates to the technical field of separated layer water injection development of oil fields, and discloses a low-permeability reservoir horizontal well injection-production section connectivity verification device and method.The device comprises a first pressure measuring cylinder, a first packer, a second pressure measuring cylinder, an oil sleeve communicating vessel and a second packer which are sequentially connected in series through an oil pipe; the head end of the first pressure measuring cylinder and the tail end of the second packer are respectively connected with an oil pipe, and the tail end of the oil pipe connected with the tail end of the second packer is plugged by a plug. The invention aims to solve the problems that whether fluid channeling exists outside a pipe or not cannot be accurately judged, the test period is long, and the safety and environmental protection risk is higher.

The invention discloses a gas injection development scheme optimization method based on carbon dioxide oil displacement, which comprises the following steps: 1) obtaining production characteristic related data of related wells using carbon dioxide oil displacement in a research area, and comparing and analyzing the production characteristics of each well; 2) selecting a general state equation set sub-simulator of numerical simulation software to carry out gas drive reservoir modeling according to reservoir characteristics of an oil area and the reality of an oil field and aiming at the characteristics of gas drive reservoir numerical simulation; 3) geologic modeling is carried out, wherein the geologic modeling comprises establishment of a grid data field, establishment of table data and establishment of a dynamic model; 4) performing oil reservoir development history fitting; and (5) according to the final oil reservoir model, injection-production parameter optimization and periodic water injection development index prediction are carried out, and an optimized test well group gas injection development scheme is obtained. According to the method, carbon dioxide oil displacement numerical simulation is carried out, corresponding reasonable mining method research and development scheme optimization research are carried out, and a scientific and reasonable water-gas alternate gas injection recovery efficiency improving scheme can be effectively guided and formulated.

The invention discloses an experimental device and method for researching dynamic waves and volume of glutenite stratum.The experimental device comprises a temperature control box and a rock core holder in the temperature control box, an experimental rock core is arranged in the rock core holder, and a plurality of sets of injection ends and extraction ends are arranged on the two sides of the rock core holder; the extraction end is connected with the liquid storage container through a pipeline, and the injection end is connected with an outlet of the displacement pump through a pipeline; the method comprises the following steps: fixing an experimental rock core for simulating glutenite in the rock core holder and putting the rock core holder in the temperature control box to simulate formation conditions; starting a displacement pump to inject an oil sample and simulated formation water into the experimental rock core in sequence, and simulating the influence of time on the dynamic evolution rule of swept volume in the oilfield development process according to the dynamic distribution of fluid between an injection end and an extraction end; and the water drive front edge position can be calculated. According to the method, a basis can be provided for oilfield water injection development, and the recovery efficiency of an oil layer can be conveniently improved by accurately regulating and controlling the water injection direction and speed in actual production.

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.