55 results about "Reservoir engineering" patented technology

The invention provides a deep energy reservoir multi-scale heat-fluid-solid coupling simulation method and system, and belongs to the field of deep energy reservoir numerical simulation. Acquiring spatial distribution characteristics and physical property parameters of different lithologic reservoir media under a micro-scale, and constructing a digital structure model of the reservoir media; a micro-observation action mechanism and a flow mechanism are embedded in the model to obtain a micro-observation numerical model; establishing a mapping relation by solving model structure parameters and physical property parameters of the microscopic numerical model under different thermal-fluid-solid coupling conditions; and on the basis of the mapping relationship, in combination with the macrogeological and engineering data of the target reservoir, establishing a macroscale heat-fluid-solid multi-field coupling control equation and solving, and outputting the multi-physics field response of the target reservoir under the given working condition. According to the method, fine simulation of physical property parameter dynamic transmission and a multi-field coupling evolution process from a micro view to a macro view is realized, and the accuracy and reliability of deep complex reservoir engineering behavior prediction are remarkably improved.

The invention discloses a global fracture conductivity ultra-long-term prediction method and system, belongs to the technical field of crossing of oil and gas reservoir engineering and artificial intelligence, and is used for solving the technical problem that the calculation cost is high when an existing physical model is used for predicting fracture ultra-long-term conductivity. The method comprises the following steps: generating a global fracture conductivity evolution data set covering multiple working conditions through a numerical simulation system; constructing a multi-channel input tensor containing dynamic fracture conductivity and static proppant concentration distribution; using the data set to train a plurality of Fourier neural operator models for different prediction time scales; and based on a hierarchical time sequence aggregation strategy, iteratively calling trained models of different time scales, and realizing rapid prediction of fracture conductivity in a few years to tens of years in the future. According to the method, on the premise of ensuring the prediction precision, the calculation time consumption of ultra-long-term prediction can be remarkably reduced, and decision support is provided for crack design and production strategy optimization.

The invention belongs to the technical field of oil and gas reservoir engineering and multiphase seepage dynamic monitoring, relates to a characterization method of seepage behaviors of multiphase fluid in a porous medium, and particularly provides a dynamic construction method of a multiphase displacement capillary pressure-saturation relationship based on nuclear magnetic resonance. Comprising the following steps: S1, acquiring a low-field nuclear magnetic resonance relaxation spectrum of a porous medium in a gas-water two-phase displacement process; s2, determining two-phase fluid interfacial tension, a wetting contact angle and a rock surface relaxation rate; s3, determining the dynamic cut-off relaxation time of the displacement stage; s4, calculating equivalent capillary pressure; the residual water saturation is calculated, and the equivalent capillary pressure is the capillary pressure corresponding to the current displacement stage and is used for constructing a capillary pressure-saturation curve. According to the method, the capillary pressure change in the porous medium can be obtained only through spectral analysis without a centrifugal or mercury injection experiment.

The invention relates to the technical field of gas reservoir engineering and development, in particular to a dynamic correction method for the storage capacity of a gas storage of a condensate gas reservoir. Comprising the following specific steps: S1, based on a gas reservoir engineering method and geological data, calculating an original gas-bearing pore volume of a gas storage, and constructing an initial material balance model and various key parameters related to the initial material balance model; according to the method, through basic data collection and model construction, experimental determination and multi-path pore volume change calculation, and then model correction, parameter review, experimental simulation and final prediction and optimization, the storage capacity related parameters can be accurately calculated and corrected, the influence of various factors on the pore volume is effectively quantified, and the calculation efficiency is improved. Accurate prediction of the storage capacity change of the gas storage under future multi-cycle injection and production is achieved, injection and production parameters are optimized to remarkably improve the working gas amount and the storage capacity utilization rate, and good economic benefits and gas storage operation benefits are brought.

This invention provides a method and computer equipment for determining the dynamic reserves of condensate gas reservoirs, belonging to the field of oil and gas reservoir engineering. The method for determining the dynamic reserves of condensate gas reservoirs includes: acquiring a set of dynamic production data from well pressure measurement of the target condensate gas reservoir; converting the oil production data in the set of dynamic production data to obtain a total converted dynamic production data set of well pressure measurement; acquiring the pseudo-pressure of the target condensate gas reservoir under original conditions; selecting dynamic production data from well pressure measurement at multiple different pressure measurement time points that meet preset conditions to obtain a production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir based on the pseudo-pressure; adjusting the production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir to obtain an adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir based on the adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir; and calculating the dynamic reserves of the target condensate gas reservoir based on the adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir.

The application discloses a kind of well group control reserves chemical flooding sweep efficiency calculation method, comprising the following steps: (1), three-dimensional fine porosity and permeability model is established;(2), well group control reserves chemical flooding sweep efficiency calculation.This method can improve the accuracy of well group control reserves chemical flooding sweep efficiency calculation, so as to provide accurate basis for chemical flooding reservoir engineering design, numerical simulation accuracy, tracking adjustment and post-evaluation of implementation effect of scheme.Compared with the traditional chemical flooding sweep efficiency calculation, the method is more scientific, the concept is clearer, the index is more quantitative, and the chemical flooding sweep efficiency calculation result is more accurate and reliable, which has important significance for guiding oilfield production and development.

The invention discloses a multi-scale analysis-based gas-water seepage field simulation method, which specifically comprises the following steps of: based on a digital rock core reconstructed by a CT (Computed Tomography) scanning image of a typical rock sample of a target reservoir, adopting a microcosmic pore network flow simulation technology; the change rule of the stratum seepage capacity in different stratum pressure gradients and water drive processes, the use degree of a pore network and the water drive process in a pore are calculated, and then a correlation chart with the rock permeability and the pressure gradients is established and used for rapid measurement and calculation of the actual reserve use degree and the recovery degree of the water-invaded sandstone gas reservoir. The method starts from a rock microcosmic pore channel, the scale is amplified to a macroscopic oil reservoir during application, the method has the cross-scale characteristic, and the method is used for rapidly measuring, calculating and evaluating the reserve utilization degree and the recovery degree of the actual water-invaded sandstone gas reservoir and is beneficial to rapid development of the gas reservoir engineering scheme design in a mine field.

The invention discloses a tight gas well unstable open-flow capacity evaluation method based on production dynamic data, and belongs to the technical field of gas reservoir engineering. The method comprises the following steps: firstly, collecting tight gas well production dynamic data and basic parameters and preprocessing; then, a deconvolution algorithm and a Duhamel principle are introduced, and variable-yield variable-pressure data are standardized into constant-pressure variable-yield data; then, in combination with a gas reservoir seepage differential equation considering natural gas compressibility, a'bottom hole flowing pressure-yield-time 'relation model is established; a yield-time function is reversely deduced, the bottom hole flowing pressure is made to be 0, and the unstable open-flow capacity is calculated; and finally, drawing a change curve, analyzing a dynamic rule and a decline mechanism, and providing reference for development countermeasures. The method realizes efficient utilization of production dynamic data, accurately captures an open-flow capacity decline rule, improves evaluation precision and timeliness, reduces cost, is suitable for unconventional gas reservoirs such as tight gas reservoirs, and provides support for efficient development of the gas reservoirs.

The invention provides a gas well productivity and EUR optimization method in the middle and later periods of dense low-permeability gas reservoir development, and relates to the technical field of gas reservoir engineering, and the method comprises the steps: collecting historical dynamic and static data of a dense low-permeability gas reservoir, and constructing index system data; based on the index system data, static and dynamic main control factor analysis influencing open flow capacity and recoverable reserves is carried out, and a main control factor set is obtained; according to the main control factor set, using a machine learning algorithm to construct a prediction model used for predicting open flow capacity and recoverable reserves; taking open flow capacity or recoverable reserve maximization as a target, and constructing a control optimization model for optimizing production control variables; and for the target well, using the prediction model to predict open flow capacity and recoverable reserves, and using the control optimization model to optimize production control variables. Compared with a traditional productivity analysis method, the method has the advantages that subjective factor interference is effectively reduced, the analysis process is more objective and efficient, and productivity and EUR evaluation under the interaction of different factors is achieved at the same time.

This invention relates to the field of reservoir engineering management technology, specifically a reservoir lifecycle management system based on spatiotemporal matrix and digital twin. The system includes a digital twin model construction module, a spatiotemporal matrix module, a data fusion module, a lifecycle simulation module, a real-time data acquisition and update module, a model dynamic adjustment module, and a management decision support module. The system uses a spatiotemporal matrix to uniformly organize and manage multi-source data throughout the reservoir's lifecycle, utilizes a digital twin model to construct a virtual representation of the reservoir, achieves bidirectional synchronization through data fusion, and dynamically adjusts model parameters based on real-time data, ultimately generating lifecycle management decision outputs. This invention solves the problems of scattered data and static models in existing technologies, improving the accuracy and reliability of reservoir management.

The application relates to the technical field of hydraulic engineering, and discloses a loess hilly area reservoir building method, which aims at the problems of dam site scarcity, low efficiency of water and soil resource development, dispersion of existing water storage projects, prominent contradiction between ecology and culture protection and the like in loess hilly areas, takes global planning and systematic management as cores, realizes organic unification of intensive water resource utilization, comprehensive benefit expansion and ecological protection through a five-step method of scheme optimization comparison, building of large reservoirs and merging of small reservoirs, function zoning, series connection of new and old projects and overall planning of ecology and culture. The method solves the pain points of high building cost, many immigrants and low benefit of reservoirs in loess hilly areas through innovative means such as multi-scheme optimization comparison, function zoning of one reservoir with two systems, reservoir excavation and reconstruction technology, land lifting and regulation and historical culture protection, and can be widely applied to reservoir engineering construction in loess hilly areas.

A well network deployment method for increasing the storage capacity of water-flooded high-permeability gas storage facilities, belonging to the field of oil reservoir gas storage construction technology, includes the following steps: S1, employing oil and gas reservoir fine description technology; S2, employing oil and gas reservoir engineering technology; S3, employing gas storage dynamic analysis technology; S4, establishing a comprehensive geological model, and combining steps S2 and S3 to clarify the direction of seepage dominance and delineate seepage zones in oil and gas areas. This invention, under conditions of high well network control and severe water intrusion and gas channeling, can significantly increase the storage capacity of water-flooded areas, solve the common problem of uneven injection-production displacement in sandstone gas storage facilities, and alleviate the contradiction of large differences in displacement effects between favorable and unfavorable areas during cyclic injection-production. This invention can be applied to the expansion of gas storage facilities that have been renovated due to significant seepage dominance or strong planar heterogeneity.

The present disclosure relates to a kind of water deep penetration guide seam fracturing reservoir engineering design methods, comprising: using water deep penetration perforation method, drill open horizontal long hole in the top of thick oil layer, the horizontal long hole is drilled in low water content direction on plane, and drainage channel is formed in the part where water drive oil capacity is weak;The penetration length of the water deep penetration perforation is determined according to the development thickness of oil layer, injection-production connection relationship, injection-production distance, the number of perforation is in the same direction on the top of each subdivision layer blocked by interlayer, and it is 0.2-0.4m away from upper barrier or interlayer;After the water deep penetration perforation, hydraulic fracturing is carried out to form artificial fracture, let the drilled horizontal long hole guide the longitudinal position and horizontal trend of artificial fracture, to improve the flow conductivity again, realize the purpose of "targeting" tapping of remaining oil enrichment site in the cubic of injection-production well positive rhythm oil layer.

The invention provides a water breakthrough time prediction method and device for an oil well in a deepwater oil reservoir, and relates to the technical field of oil reservoir engineering. Establishing a target function of the dynamic relative permeability of the rock core in the deep water reservoir and the displacement speed and water saturation of the rock core; determining the derivative of the target function at the water saturation of the water drive front; and predicting the water breakthrough time of the oil well in the deepwater reservoir according to the derivative, the static pressure of the deepwater reservoir, the formation pressure of the deepwater reservoir, the porosity of the reservoir in the deepwater reservoir, the pore volume in the seepage region between the injection wells and the production wells, the target water injection rate of the oil well and a target formula. Therefore, on one hand, the influence of the dynamic relative permeability on the water breakthrough time is considered, the accuracy of water breakthrough time prediction is improved, on the other hand, the waterless oil production period of the oil well is prolonged, the accumulated oil production and the recovery efficiency of the oil well are improved, and a basis is provided for subsequent development and adjustment.

The invention belongs to the technical field of reservoir engineering application, and discloses a digital-analog characterization method for reservoir pressure drive seepage parameters, which comprises the following steps: S1, measuring the permeability and relative permeability of a stratum sample before pressure drive, manufacturing artificial microfractures in a reservoir, converting original stratum pore seepage into artificial fracture net seepage, and calculating the permeability of the stratum sample before pressure drive; performing a water injection experiment on the sample by adopting different displacement pressure gradients, and determining the change relation of the permeability of the reservoir sample along with the pressure and the change condition of relative permeability before and after the matrix fracture pressure is reached in the water injection experiment process; s2, calculating the limit wave and radius under the pressure-driven water injection condition; and S3, carrying out digital-analog characterization on the oil reservoir pressure-drive water injection seepage parameters. According to the method, the permeability and relative permeability parameters are adjusted in real time by using the pressure as a reference condition, and full-life-cycle seepage parameter characterization in the pressure driving process is equivalently completed.

The invention provides a reservoir spillway flood regulation calculation method and device and electronic equipment, and the method comprises the steps: firstly selecting a reservoir original design flood hydrograph of a frequency corresponding to a target standard, then selecting a gate control working condition of a reservoir spillway, and carrying out the regulation calculation of the flood of the reservoir spillway based on the reservoir original design flood hydrograph and a reservoir original discharge capacity curve; and determining a reservoir design flood hydrograph and a reservoir discharge capacity curve corresponding to the gate control working condition, and then performing flood regulation calculation by adopting a water balance method based on the gate control working condition, the reservoir design flood hydrograph, the reservoir discharge capacity curve, the normal storage level of the reservoir and the water level storage capacity curve of the reservoir to obtain a reservoir flood regulation hydrograph. By adopting the method, the efficiency and the accuracy of reservoir flood regulation calculation can be improved, so that the working efficiency of reservoir project spillway type comparison and selection can be improved.

The invention discloses a gas reservoir development potential assessment method based on water seal gas influence, and relates to the technical field of oil and gas field development. Comprising the following steps: determining the type of each gas well water invasion mode according to a water invasion substance balance chart; based on the types of the water invasion modes of all the gas wells, the gas wells with water invasion and natural gas packing are screened out; according to the pressure point of each well in the water invasion substance balance chart, fitting and predicting recoverable reserves and water seal gas quantity of each single well; and based on the recoverable reserves and the water seal gas volumes of all the single wells in the gas reservoir, the proportions of the recoverable reserves and the water seal gas volumes in the dynamic reserves of the corresponding single wells are calculated so as to determine the overall development potential of the gas reservoir. On the basis of the gas reservoir engineering method, the recoverable reserves and the water seal gas quantity of each single well are determined, the development potential evaluation of the gas reservoir is realized, the water invasion influence of the water-containing gas reservoir is fully considered, the development potential of the gas reservoir is accurately evaluated, and reliable guidance is provided for the development strategy of the water-containing gas reservoir.

The invention provides a maximum horizontal principal stress obtaining method based on a Mohr-Coulomb criterion, and belongs to the technical field of reservoir rock mechanics research. The maximum horizontal principal stress obtaining method comprises the steps that formation pore pressure and rock strength parameters are obtained through comprehensive logging data, and drilling fluid column pressure is calculated through drilling fluid density data; measuring the minimum horizontal principal stress; the well wall caving width is obtained through the dual-hole-diameter logging data; according to a calculation equation, factors such as tectonic stress, drilling working conditions and formation fluid are fully considered in the method, and the well wall caving width is obtained through well logging information; indoor rock core testing is not needed; the calculation precision is high, and a scientific basis is provided for oil reservoir engineering, drilling engineering and yield increase engineering.

The present application relates to a kind of oil reservoir FWAG injection-production parameter determination method, device and equipment, it is related to oil reservoir engineering technical field, including: the target numerical simulation model for representing the target oil reservoir FWAG injection-production process is constructed;Based on the target numerical simulation model and preset general FWAG strategy model, the basic FWAG strategy of target oil reservoir is determined;The reservoir state data of target oil reservoir is acquired;Based on the reservoir state data, using the basic FWAG strategy carries out injection-production simulation;Injection-production simulation result is input into the target numerical simulation model, and injection-production simulation feedback data is obtained;According to the injection-production simulation feedback data, with the production efficiency and stability of target oil reservoir FWAG injection-production process maximization as goal, the basic FWAG strategy is optimized;Based on the basic FWAG strategy after optimization, the FWAG injection-production parameter of target oil reservoir is determined.

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

This invention belongs to the field of oil and gas field reservoir engineering technology, specifically a method for characterizing the impact of clastic reservoir heterogeneity on reservoir efficiency. First, mineral composition, porosity and permeability, mechanical parameters, and spatial configuration of the study area are obtained. Based on the interlayer spatial configuration, flow units are divided to quantitatively evaluate the constraints of interlayers on effective reservoir space. Through creep experiments and alternating load experiments, mechanical property degradation models of different types of interlayers under long-term high pressure and injection-production cycles are established. A dynamic model of interlayer sealing capacity evolution is constructed to quantify its long-term potential to suppress vertical fluid flow. By coupling the interlayer volumetric sweep efficiency, the mechanical degradation model, and the sealing capacity evolution model, a comprehensive reservoir efficiency impact coefficient is established, enabling a quantitative evaluation of reservoir efficiency under different types of interlayer constraints. This invention elevates the impact of interlayer heterogeneity on reservoirs from a static description to a dynamic quantitative evaluation, providing a scientific basis for the site selection optimization and injection-production strategy formulation of underground reservoirs.

The invention relates to a fluid injection control method and system. The method comprises the steps that temperature distribution simulation is conducted according to reservoir geological information and reservoir engineering information to obtain a reservoir temperature distribution model; based on a preset discrete grid size and according to the standard fluid injection parameters, performing measurement and control configuration analysis operation on the reservoir temperature distribution model, obtaining measurement and control equipment layout information corresponding to each discrete grid, and constructing a reservoir data acquisition system, a reservoir temperature array, a reservoir pressure array and a reservoir flow velocity array are obtained and serve as monitoring data to be integrated into a reservoir temperature distribution model, and the reservoir temperature distribution model is dynamically updated and calibrated to obtain a reservoir production dynamic model; constructing an injection optimization space according to the fluid injection constraint and the reservoir production dynamic model; and based on a preset injection optimization target, fluid injection control parameters are obtained through analysis of the injection optimization space, and injection of the fluid is controlled. And the fluid injection control precision degree of the ultra-high-temperature long horizontal well section reservoir can be improved.

The invention discloses an end-to-end reservoir parameter inversion method based on a consistency model and phase control constraint, and relates to the technical field of reservoir engineering. The method comprises the following steps: firstly, acquiring geological parameters and production dynamic data of a target area, constructing a sample database and carrying out data preprocessing, then constructing a consistency model and an improved U-shaped network, and integrating the consistency model and the improved U-shaped network to construct an end-to-end oil reservoir parameter inversion model considering phase control constraint; and training and verifying the end-to-end oil reservoir parameter inversion model by using the database, and after the end-to-end oil reservoir parameter inversion model is optimized, performing oil reservoir end-to-end history fitting on a specified oil reservoir by using the end-to-end oil reservoir parameter inversion model, and inverting an oil reservoir geological parameter field. According to the method, the physical mechanism constraint is combined with a model efficient generation method, the consistency model and the sedimentary facies distribution constraint are introduced into the end-to-end oil reservoir parameter inversion model, the inversion robustness of the end-to-end oil reservoir parameter inversion model is improved, and technical support is provided for accurate inversion of an oil reservoir geological parameter field.

This invention provides a method and system for calculating development indicators of polymer flooding reservoirs, belonging to the field of reservoir engineering. The method includes: initializing the split flow rate data of each oil layer and the split flow rate data of the flow tubes based on the seepage characteristics of the polymer flooding reservoir at different development stages, the initial flow tube distribution data corresponding to the target well network, and the initial oil layer data of the target well network, to obtain an initial state; based on the initial state, determining the split flow rate data of each oil layer and the split flow rate data of the flow tubes at each moment during the water injection process, starting from the start of water injection; updating the displacement process leading edge distance data and development indicator data for characterizing the development status of the displacement process of the target well network in real time according to the split flow rate data of each oil layer and the split flow rate data of the flow tubes at each moment during the water injection process; and stopping water injection when the water injection status data of the target well network reaches a preset stopping condition. This method reduces the computational difficulty while accurately calculating the development dynamics of the target well network.

The invention relates to the field of oil reservoir engineering research, in particular to a method for quantitatively evaluating the connectivity degree between river sand oil-water wells based on connectivity factors. The method mainly solves the problems that an existing connectivity evaluation method is not comprehensive enough, evaluation parameters are not easy to obtain, and evaluation objects are limited. Comprising the following steps: acquiring a deposition unit boundary database and logging curve data, and establishing a small-layer hierarchical database; calculating the blending average permeability, the connectivity coefficient and the stage difference of the oil-water well; normalizing the harmonic average permeability, the connectivity coefficient and the stage difference; the influence weights of the relative permeability, the relative connectivity coefficient and the relative stage difference after normalization on the connectivity degree are determined, and a connectivity factor formula is established; and determining a connectivity factor, and evaluating the connectivity of the oil-water well. According to the method, evaluation parameters are easy to obtain, the connectivity of the sand bodies between the oil wells and the water wells in spatial distribution and the connectivity of seepage parameters are comprehensively considered, the seepage connectivity condition of fluid in the sand bodies between the wells can be accurately indicated, and evaluation factors are more comprehensively considered.

The invention discloses a full-depth reservoir physical and mechanical parameter characterization method, device, equipment and medium, and relates to petroleum and natural gas development, the method comprises the following steps: obtaining and processing multi-source data in a reservoir shaft range, and constructing a generative artificial intelligence model; a prediction parameter result of the artificial intelligence model is constrained and corrected, the preprocessed multi-source data is jointly input into the artificial intelligence model, the artificial intelligence model is driven to perform fusion completion on reservoir physical and mechanical parameter results subjected to constraint correction, and a full-depth parameter field is formed; constructing a numerical simulation model based on the parameter field, and simulating a reservoir mechanical response process to obtain a simulation result; and performing inversion and iterative correction on the parameter field by using a simulation result to obtain a physical and mechanical parameter characterization result of the target full-depth reservoir. According to the method, multi-source data fusion, AI driving and simulation inversion closed loop are achieved, the integrity and reliability of reservoir physical and mechanical parameter representation are remarkably improved, and the method is suitable for different types of reservoir engineering.

The invention discloses a combined dispatching method for pumped storage power stations serving multiple power grid main bodies and conventional hydropower stations, belongs to the technical field of water conservancy projects, and can solve the problems that the peak regulation capacity of an existing dispatching system is limited, and power resource optimization configuration oriented to the multiple power grid main bodies is difficult to support. The method comprises the following steps: S1, according to hydrological data and reservoir engineering data of a cascade reservoir group and power station engineering data of a pumped storage power station, constructing operation scenes of the cascade reservoir group and the pumped storage power station and an intra-day joint peak regulation scheduling model; s2, constructing a model constraint, and constructing a target function of multi-target optimization of the intra-day joint peak regulation scheduling model; s3, determining an optimal scheduling solution of the intra-day joint peak regulation scheduling model under each single target of the target function; and S4, determining a combined scheduling strategy of the cascade reservoir group and the pumped storage power station according to the optimal scheduling solutions under all the single targets. The method is used for combined dispatching of the pumped storage power station and the conventional hydropower station.

The present application relates to a kind of phase-controlled reserves chemical flooding wave and coefficient calculation method, comprising the following steps: (1), establish high-precision three-dimensional porosity and permeability model;(2), calculate phase-controlled reserves chemical flooding wave and coefficient.This method can improve the accuracy of phase-controlled reserves chemical flooding wave and coefficient calculation, thereby providing accurate basis for chemical flooding reservoir engineering design, numerical simulation accuracy, tracking adjustment and post-evaluation of implementation effect of scheme.Compared with the traditional chemical flooding wave and coefficient calculation, the method is more scientific, the concept is clearer, the index is more quantitative, and the chemical flooding wave and coefficient calculation result is more accurate and reliable, which has important significance for guiding oilfield production and development.