59 results about "Darcy" patented technology

The invention relates to a low-permeability shale gas-water two-phase relative permeability determination method and system, T2 spectrum curves corresponding to different pretreatment modes are obtained based on nuclear magnetic resonance, the moisture occurrence state in sample pores is determined, the pore types of low-permeability shale are divided, and corresponding critical pore sizes are obtained; according to a Hagen-poiseuille equation and gas-water distribution characteristics of different pore types, determining the flow velocity of a gas phase and a water phase in a single shale pore, and determining the corresponding fluid flow in the single pore according to the flow velocity; the total flow of gas-water two-phase fluid in the low-permeability shale pore network is obtained based on the fractal theory, the critical pore diameter and the flow; based on the total flow velocity, the phase permeability of the gas phase and the water phase and the absolute permeability of the low-permeability shale are obtained through the Darcy law, and the relative permeability is determined; and according to the distribution characteristics of the gas-water two-phase fluid in the pores, determining the water saturation of the low-permeability shale, and determining the gas-water relative permeability of the low-permeability shale under different water saturation.

The invention relates to the technical field of oil exploration and development, and particularly provides a numerical simulation method for CO2 storage and oil displacement development effect evaluation. The method comprises the following steps: constructing a flow state physical model after CO2 enters a reservoir; according to the flow state physical model, a seepage model of CO2 entering the reservoir is established by combining the Darcy seepage theory and the mass conservation theory, and an oil phase formula, a water phase formula and a CO2 gas phase formula are obtained in a radial one-dimensional cylindrical coordinate system; dividing a calculation area into differential grids according to an oil phase formula, a water phase formula and a CO2 gas phase formula to obtain a limited number of grid nodes, and replacing a continuous solution domain with the limited number of grid nodes; according to the solution domain, calculating to obtain a relation expression of CO2 saturation changing along with radius and time; a prediction model is formed through the change relational expression, the CO2 storage or oil displacement state is predicted, the CO2 storage and oil displacement process is accurately simulated, and the CO2 emission reduction effect and potential can be effectively improved.

The invention provides a heterogeneous reservoir seepage simulation method based on PIKAN, and belongs to the technical field of heterogeneous reservoir development, and the method comprises the following steps: S1, using three independent KANs to respectively approximate PIKAN of pressure p, velocity component vx and velocity component vy; and S2, constructing a loss function of a mixed pressure-speed formula including the residual error of the mass conservation equation, the residual error of the Darcy law and the residual error of the related boundary condition, and optimizing the loss function. According to the heterogeneous reservoir seepage simulation method based on the PIKAN, KAN is introduced into porous medium flow simulation for the first time, and a preliminary reference is provided for developing a general seepage simulation tool based on the PIKAN.

The invention discloses a fracturing optimization method and system for preventing pressure channeling of a deep shale reservoir and a medium, and belongs to the technical field of shale oil and gas geological exploitation. Comprising the following steps: acquiring different-scale fracture characteristics and ground stress distribution rules of a deep shale reservoir; different-scale fracture mechanical parameters and seepage parameter characteristics of the rock sample are obtained; building a deep shale reservoir multi-physics coupling fracturing model by using a damage mechanics theory according to deep shale reservoir matrix characteristics; the method comprises the following steps: setting parameters according to solid mechanics, porous media and Darcy law based on a deep shale reservoir and different-scale fracture characteristics, and establishing a platform fracturing numerical model; on the basis of a platform fracturing numerical model, an optimal fracturing chart influenced by multi-scale fracture development is obtained through orthogonal experimental simulation, so that a fracturing parameter combination enabling the effective fracturing volume to be maximum and avoiding inter-well pressure channeling is determined; according to the fracturing optimization method for preventing pressure channeling of the deep shale reservoir, efficient development of deep shale oil and gas is effectively guaranteed.

The invention relates to the technical field of petroleum and natural gas drilling engineering, and particularly discloses a multi-field coupled complex fractured formation fracture width distribution inversion method, which is characterized in that a drilling fluid leakage model considering a fluid-solid coupling effect is constructed based on a porous elastic mechanics theory, and a roughness correction factor is introduced to correct a traditional cubic law; the application of the Darcy law in the matrix is perfected, a matrix and crack coupled drilling fluid leakage mathematical model is established, the influence rule of key parameters such as fluid viscosity, pressure difference and crack width on the drilling fluid leakage amount is obtained through numerical simulation, and on the basis, the drilling fluid leakage amount is calculated. According to the method, the crack width multiple linear regression inversion equation with the fluid viscosity, the pressure difference and the accumulated leakage as independent variables is established, the inversion equation has high prediction precision and practicability and can be used for rapidly and accurately inversing the crack width on site, and theoretical and technical supports are provided for multi-scale fractured formation leakage mechanism understanding and leakage prevention and control optimization.

The invention provides a method for predicting the diffusion range of grouting slurry in a coal seam floor area. The method comprises the following steps: acquiring a slurry flooding model containing well field stratum parameters and grouting drilling parameters in the coal seam floor area; based on a Navier Stokes equation and a Darcy law, obtaining a Brinkman equation used for describing incompressible fluid flow caused by the reinforcing material in the porous medium; wherein the Brinkman equation comprises a viscosity item and a pressure gradient item; the grouting pressure, the slurry density, the dynamic viscosity, the porous medium permeability and the porous medium porosity serve as influence factors of slurry diffusion, and various parameter combinations of the influence factors and levels are obtained; and simulating a slurry diffusion process based on the slurry flooding model by using a plurality of parameter combinations and utilizing the Brinkman equation so as to obtain an optimal parameter combination and a corresponding slurry diffusion range. According to the method, the slurry diffusion range can be scientifically and accurately predicted, and the consistency and reliability of the grouting treatment effect are improved.

The present application relates to oil and gas field development technology, disclose a kind of heavy oil reservoir hot water drive limit well spacing determination method. Including the following steps: S1, the starting pressure gradient corresponding to different temperature is obtained by percolation experiment test;S2, according to the starting pressure gradient corresponding to different temperature, determine the inflection point temperature of starting pressure gradient curve;S3, based on the inflection point temperature of pressure gradient curve, the percolation area between injection well and production well is divided;S4, based on the percolation area divided, the percolation resistance R of darcy percolation area between injection well and production well is calculated d ;S5, based on R d The pressure drop ΔP of darcy percolation area between injection well and production well is calculated d ;S6, based on ΔP d The length l of non-darcy percolation area between injection well and production well is calculated nd ;S7, based on l nd Determine the limit well spacing L of heavy oil reservoir hot water drive. The determination method can guide the formulation of heavy oil reservoir hot water drive development plan, improve development effect.

The present application relates to the technical field of seepage mechanics, and particularly relates to a conical sealing surface leakage rate calculation method based on Darcy's law, comprising the following steps: a W-M function is used to simulate the random topography of the workpiece surface at a microscale, and a normalization method is used to generate surface point cloud data meeting roughness requirements; according to the surface point cloud data, a contact mechanics model is used to solve the change law between the contact state and the external load, and according to the Hertz contact theory, the contact between the rough surfaces is reconstructed as the contact between a rigid plane and a flexible rough surface; the surface is discretized into a three-dimensional grid model, the effective porosity is screened and calculated by using the connected domain discrimination method; a micro-leakage rate calculation method for the conical sealing surface in the flared pipe joint is obtained based on the effective porosity and the seepage mechanics theory algorithm; the leakage rate of the conical sealing interface is calculated, and the sealing performance of the interface is quantitatively evaluated. The present application improves the comprehensiveness and accuracy of the sealing performance evaluation.

The invention discloses a medium dehydration intrinsic dynamics law detection system and an analysis method, and relates to the field of dehydration rate testing. According to the medium dehydration intrinsic dynamics law analysis method, the dehydration rate and the Darcy seepage resistance of a to-be-detected medium in a rapid dehydration stage are obtained, and the permeability, the pre-exponential factor and the dehydration activation energy of the to-be-detected medium are calculated according to the dehydration rate and the Darcy seepage resistance of the to-be-detected medium in the rapid dehydration stage. And further predicting the dehydration rate of the to-be-detected medium in other dehydration stages. According to the medium dehydration intrinsic dynamic law detection system and the analysis method, medium intrinsic dehydration dynamic parameters are obtained through inversion of a seepage model and a desorption dynamic model according to different dehydration mechanisms in different stages of a to-be-detected medium; therefore, the method is used for predicting the medium dehydration rate under different working conditions according to the intrinsic dehydration kinetic parameters of the medium, and the problems that a traditional medium dehydration test method can only obtain the apparent dehydration rate and the test result is poor in universality along with the change of the test conditions are solved.

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 relates to the technical field of gas reservoir exploitation, and provides a water breakthrough time prediction method and device for an abnormal high-pressure gas reservoir horizontal well. The water breakthrough time prediction method for the horizontal well in the abnormal high-pressure gas reservoir comprises the following steps: establishing a gas phase motion equation of the horizontal well according to a characterization parameter of a non-darcy effect, a characterization parameter of a pulse effect and a characterization parameter of a stress sensitive effect of the horizontal well in the abnormal high-pressure gas reservoir; establishing a water phase motion equation of the horizontal well according to the characterization parameters of the Darcy flow and the characterization parameters of the stress sensitive effect of the horizontal well; and predicting the water breakthrough time of the horizontal well according to the gas phase motion equation and the water phase motion equation. According to the implementation of the method, a theoretical basis can be provided for optimization design of an abnormal high-pressure gas reservoir development scheme, and meanwhile, reliable technical support is provided for formulating and adjusting field water control measures, so that the gas reservoir development efficiency is effectively improved.

The present invention discloses a numerical simulation method and system for hydrocarbon migration and accumulation based on component equations. The method includes: establishing a basic equation and an auxiliary equation, where the basic equation is a system of partial differential equations based on component mass balance, including an accumulation term, a Darcy seepage term, a compaction term, and a source-sink term; discretizing the system of partial differential equations using the finite volume method to obtain a finite volume equation; performing a fully implicit solution to the finite volume equation to obtain the main unknowns of the system of partial differential equations; obtaining the remaining unknowns of the system of partial differential equations based on the auxiliary equation according to the obtained main unknowns; and performing numerical simulation of hydrocarbon migration and accumulation based on the solved system of partial differential equations. The system: when a processor executes a computer program stored in a memory, the method is implemented. According to the present invention, it is possible to solve the problem that the existing numerical simulation method for hydrocarbon migration and accumulation based on Darcy seepage cannot accurately simulate hydrocarbons with variable component contents during basin evolution.

The invention relates to the technical field of oil and gas reservoir engineering, in particular to a quantitative treatment method for a relative permeability curve. The method comprises the following steps: deriving a water content formula according to a relative permeability curve and a Darcy law; obtaining an oil content formula according to the obtained water content formula; s2, fitting oil production error coefficient parameters are introduced, and the corrected oil content is calculated in cooperation with the oil content formula obtained in the step S2 under the condition that the liquid production is not changed; determining the corrected water content according to the obtained corrected oil content, and establishing a relative permeability curve water phase permeability correction equation by combining the Darcy law; and S4, compiling a VBA relative permeability adjustment program according to an excel vba technology, and performing quantitative processing programming on the data calculated by the correction equation obtained in the step S4 through the adjustment program. According to the method provided by the invention, the relative permeability block is quantitatively adjusted by applying the method, and the working difficulty of historical fitting of traditional numerical simulation is solved.

The invention relates to the technical field of oil and gas field development engineering, carbon storage engineering, underground hydrogen storage technology, underground fluid seepage mechanical experiment technology and rock core displacement simulation devices, and particularly discloses a variable-diameter rock core displacement simulation device and method for simulating underground fluid migration in a near wellbore area. In order to solve the problem that a traditional equal-diameter rock core displacement device cannot simulate sudden drop of flow velocity and pressure gradient when fluid in a near wellbore zone flows radially, the device adopts a variable-diameter rock core design, the diameter of the variable-diameter rock core is gradually increased in the flowing direction, and a back pressure control system, a confining pressure system and a multi-point pressure measuring structure are matched. Under the fixed injection flow, the cross sectional area of the rock core is increased, so that the Darcy flow velocity and the pressure gradient are suddenly reduced from the injection end to the output end, and the flowing environment of the immediate vicinity of a wellbore is directly reproduced. The device can directly and efficiently simulate and test the phase state behavior, rheological property and seepage law of complex fluid under the condition of sudden change of the flow velocity and pressure gradient in the immediate vicinity of wellbore, and the engineering representativeness of experimental data is remarkably improved.

The invention discloses a method for calculating gas flow in a partitioned ventilation hose of a long tunnel. The method comprises the following steps: acquiring a friction coefficient of the inner wall of the ventilation hose and an air volume loss coefficient per unit length; according to the Darcy-Weistbach equation, pressure loss caused by friction force when gas flows through the unit length in the ventilation hose is calculated; calculating gas quantity change of gas flowing through unit length in the ventilation hose and pressure loss caused by gas loss; decomposing the pressure loss of the gas flowing through the unit length in the ventilation hose into friction pressure reduction and air volume loss pressure reduction, and establishing a differential equation to solve a change equation of the gas flow rate and the gas volume in the hose along with the longitudinal length; and establishing a relational expression among the power of the exhaust fan, the pressure difference and the initial air volume, obtaining a final calculation method of the air flow rate and the air volume in the ventilation hose, discharging dirty air generated by blasting in long and large tunnel construction out of the tunnel according to the speed conforming to the specification, achieving the purpose of ventilation in the long and large tunnel construction hole, and guaranteeing a safe and comfortable tunnel environment.

The present invention discloses a method for simulating the Darcy seepage experiment of a core and calibrating the permeability parameter, which comprises the following steps: S1, generating particles by using the PFC software and assembling the particles to simulate the rock sample; S2, setting the opening degree of the fluid domain channel, generating a fluid domain network in the pore throats of the rock sample by using the PFC fluid-solid coupling algorithm, and setting the injection and outflow conditions of the fluid at the inlet and outlet ends of the rock sample by using the fluid domain network; S3, monitoring the flow rates at the inlet and outlet ends of the rock sample based on the numerical simulation process of simulating the fluid displacement through the core, and simultaneously measuring the magnitude of the rock permeability; when the flow rates at the inlet and outlet ends of the rock sample are stable, the permeability of the rock sample is measured and calculated at this time; S4, if the permeability does not meet the requirements of subsequent numerical simulations, then the opening degree of the fluid domain channel is modified again, and S2-S3 are repeated until the permeability of the rock sample measured and calculated meets the requirements of subsequent numerical simulations, and the calibration work is completed.

The application provides a shale gas accumulation type determination method, which comprises the following steps: according to the throat radius of connected pores in the shale sample in the bedding direction, the connected pores are classified; according to the volume of each type of connected pores, the accumulation type of the shale gas is determined; wherein, the types of the connected pores include Darcy diffusion type connected pores, slip flow type connected pores, Fick diffusion type connected pores and Knudsen diffusion type connected pores. The determination method can more accurately determine the accumulation type of the shale gas.

The application discloses a metamaterial flow uniformity maintaining device, a preparation process and application. The metamaterial flow uniformity maintaining device comprises a transition part, a first maintaining part and a second maintaining part. The transition part is in an arc shape, and the radius satisfies R1 < r < R2. The transition part, the first maintaining part and the second maintaining part are all made of a metamaterial. In the embodiments of the application, a two-dimensional or three-dimensional flow uniformity maintaining device conforming to a condition formula for maintaining the flow uniformity in a variable channel obtained according to the Darcy law and corresponding boundary conditions is constructed. The device has sufficient theoretical basis and high reliability. The flow uniformity maintaining device can maintain the flow uniformity of fluid after the fluid passes through a contraction or expansion pipeline, reduces the pressure drop and resistance of the fluid in the flow process, and further guarantees the stability and uniformity of the fluid in the variable channel flow.

The application discloses a layered soil foundation pit steady seepage analytic method, system and medium, based on the steady seepage Darcy law, the seepage field around the foundation pit is divided into three regular regions, the non-homogeneous equation group is constructed by using the region continuous condition and the orthogonality of the Fourier series to solve the seepage field distribution inside and outside the foundation pit, and the analytic solution of the hydraulic head of the layered soil is obtained. The analytic solution of the hydraulic head of the layered soil is simple in form, high in precision, convenient and applicable, fills the blank of the current analytic research on the seepage of the layered soil of the foundation pit, reveals the distribution law of the seepage field inside and outside the foundation pit, and is very meaningful for the application of the foundation pit engineering.

A detection system and analysis method for the intrinsic kinetics law of medium dehydration, which relates to the field of dehydration rate testing. The analysis method for the intrinsic kinetics law of medium dehydration obtains the dehydration rate and Darcy seepage resistance of the medium to be detected in the rapid dehydration stage, calculates the permeability, pre-exponential factor and dehydration activation energy of the medium to be detected based on the dehydration rate and Darcy seepage resistance of the medium to be detected in the rapid dehydration stage, and then predicts the dehydration rate of the medium to be detected in other dehydration stages. The detection system and analysis method for the intrinsic kinetics law of medium dehydration respectively use a seepage model and a desorption kinetics model to invert the intrinsic dehydration kinetic parameters of the medium according to the different dehydration mechanism mechanisms in different stages of the medium to be detected, so as to predict the dehydration rate of the medium under different working conditions based on the intrinsic dehydration kinetic parameters of the medium, and solves the problems that the traditional medium dehydration test method can only obtain the apparent dehydration rate and the test results vary with the test conditions and lack universality, etc.

The invention relates to a method for testing the dynamic permeability coefficient of a defective geomembrane impermeable layer, and aims to evaluate the permeability and stability of a geomembrane with defects (such as holes) under different water heads. The method comprises the following steps: measuring the grain composition of a soil sample, preparing a defective geomembrane impermeable layer and carrying out water head saturation; carrying out penetration test step by step according to the multi-stage penetration gradient parameters, recording the penetration amount, the seepage pressure and the seepage phenomenon, and calculating the penetration coefficient under each stage of penetration gradient. And finally, fitting permeability coefficient data through a statistical method, analyzing the change trend of the permeability coefficient data, and evaluating the influence of defects on the performance of the impermeable layer. According to the method, the axial symmetry penetration model is established, it is assumed that water flow meets laminar flow conditions and meets the Darcy law, and an effective experimental basis is provided for permeability analysis of geomembrane defects. The method can be widely applied to performance evaluation and quality detection of geomembrane anti-seepage engineering.

The present application relates to a kind of thick sandstone reservoir gravity gas drive productivity prediction method, device, medium and equipment, method includes the following steps: with the Dietz model of inclined gas cap reservoir gas drive oil as the basis, longitudinal with gas-oil displacement front as limit the entire thick sandstone reservoir is divided into unsaturated zone and saturated zone, the volume of remaining oil, residual oil and oil film in two regions is analyzed and calculated, with material balance equation and Jeffreys equation as the basis, material balance relationship is established;Based on material balance relationship and Darcy percolation formula, establish thick sandstone reservoir gravity gas drive productivity prediction mathematical model 1;Combining Kozeny formula, oil and gas J function, establish thick sandstone reservoir gravity gas drive productivity prediction mathematical model 2;Based on mathematical model 1 and mathematical model 2, the size of thick sandstone reservoir gravity gas drive productivity at any time is calculated.The method greatly improves the practicability of thick sandstone reservoir gravity gas drive productivity calculation model.

The invention discloses a method for realizing a fluid stealth effect by regulating and controlling permeability in a porous medium through a conformal auxiliary tracking method. The method comprises the following steps of: solving a Darcy flow field control equation in a porous medium to generate an orthogonal conformal grid formed by streamlines and isobaric lines; in combination with the Darcy law, scalar distribution of isotropic permeability is designed along a flow line and an isobaric line, then pressure boundary conditions and speed boundary conditions are accurately matched, the influence of geometric distortion on a flow field is compensated, extension invariance of a conformal grid is maintained, uniform streaming of fluid in a target area is completed, and the stealth function of the Darcy flow field is achieved. According to the method, the porous medium metamaterial model with the permeability capable of being precisely regulated and controlled is given, a fluid regulation and control mechanism based on geometry-physical cooperation is constructed through conformal scalar design of isotropic permeability, and the method is suitable for functional areas in any shape and has important application value in micro-fluidic stealth, underground water pollution isolation and thermal management optimization.

The present invention discloses a method and system for optimizing the permeability coefficient based on the tidal influence of offshore pumping tests, and belongs to the technical field of offshore pumping tests. The sea level height data is obtained through tidal monitoring equipment and an equally spaced sampling sequence is generated, and the water level and groundwater ion concentration in the pumping well are synchronously collected; the main frequency of the tidal signal is dynamically tracked and the time domain translation scale is quantified, and the real-time permeability coefficient is estimated based on Darcy's law; a fuzzy error prediction function and a Kalman filter optimization model are constructed to predict the permeability coefficient adjustment amount; key parameters are dynamically optimized through a discrete time parameter update model and fed back to the system. By integrating the dynamic influence of tides with the response characteristics of groundwater, the present invention solves the problem of permeability coefficient calculation errors caused by tidal fluctuations in traditional pumping tests and can quickly respond to tidal influences, significantly improving the accuracy and real-time performance of offshore hydrogeological parameter assessment.

The invention relates to the technical field of seepage prediction in subsea tunnel engineering, and discloses a subsea tunnel water seepage amount prediction method under the grouting reinforcement effect, and the method comprises the following steps: S1, defining a physical model which is used for describing the seepage behavior of a subsea tunnel under the grouting reinforcement condition; s2, analyzing an aquifer area of the fractured rock mass; s3, the grouting circle area is analyzed; and S4, carrying out coupling solution and output, and according to the flow continuity condition on the outer boundary of the grouting ring, analyzing and decoupling the aquifer region and the grouting ring region. According to the method, non-linear seepage under the high water head condition is described in the aquifer area through the I zbash law, meanwhile, linear seepage in a low-permeability medium is reflected in the grouting circle area through the Darcy law, and the characteristic difference of media in different areas and the non-linear seepage effect of fractured rock mass under the high water head are considered; and the accuracy of predicting the water seepage amount of the subsea tunnel under the complicated geological conditions of high water head, high-permeability fractured rock mass and the like is improved.

The invention discloses a Bernoulli equation-based concrete pumping pressure loss calculation method, which comprises the following steps of: firstly, constructing a concrete pumping pressure loss unary flow model based on concrete pumping flow characteristics; secondly, the equivalent diameter and the Reynolds number of a lubricating layer are calculated according to the concrete pumping rheological behavior; a reverse modeling tool is adopted to scan and construct the geometrical shape of the aggregate particles, the equivalent particle size of the non-spherical aggregate particles is obtained through the hydraulic radius, and then the relative roughness of the aggregate particles is calculated; then establishing an energy conversion equation between the two overflowing sections according to fluid state parameters of the overflowing section 1 and the overflowing section 2 by utilizing a Bernoulli equation and a continuity equation, and obtaining a calculation formula of a pressure difference of the two overflowing sections according to the energy conversion equation; and finally, calculating a pressure intensity loss value between the two cutoff surfaces by combining a Mody formula and a Darcy formula. According to the method, the calculation steps are simple, and a theoretical basis is provided for subsequent pump truck design and concrete pumping pressure adjustment.

The present invention discloses an efficient hydrodynamic simulation method for an energy absorption / dissipation type marine structure, belonging to the technical field of ocean wave energy utilization. Instantaneous flow rate data is obtained, non-linear resistance is introduced, and a hydrodynamic simulation method is determined based on the Darcy-Forchheimer equation; the resistance coefficient of the perforated plate is calculated by combining the porosity and geometric characteristics of the perforated plate with empirical formulas; a reconstructed geometric model of the OWC device is established, meshed, a porous medium region and an inserted source term are set, and numerical simulation is carried out to obtain data and verify the efficiency of the dynamic behavior of the fluid. Taking the oscillating water column (OWC) wave energy device as an example, the present invention introduces a porous medium to replace the traditional small orifice and perforated plate damping methods, solves the problem of low calculation efficiency caused by small orifices, and at the same time calculates the non-linear resistance coefficient using the Darcy-Forchheimer formula. Finally, numerical simulation and verification are carried out to ensure the high precision of the simulation results, providing a scientific basis and technical support for subsequent hydrodynamic numerical simulation methods.

The embodiment of the invention discloses a well pattern economy evaluation method and device, equipment and a medium. The method comprises the following steps: calculating an oil phase seepage velocity of a target grid based on a Darcy formula; determining a target flow velocity interval to which a target grid belongs according to an oil phase seepage velocity threshold and the oil phase seepage velocity; and determining an economic evaluation result of the target well pattern according to the target speed interval to which each grid belongs. According to the technical scheme, the target flow velocity interval to which the oil phase seepage velocity of the target grid belongs is determined through the oil phase seepage velocity threshold value, then the economical efficiency evaluation result of the target well pattern is determined according to the target velocity interval to which each grid belongs, the relation between fluid flow in the stratum and economic benefits is established, and the economic efficiency of the well pattern is improved. The well pattern is evaluated from the perspective of economy, namely, the control degree of the well pattern is reflected from the perspective of economy.

This invention discloses a method for calculating the pressure of different zones in shale oil and gas reservoirs based on fluid exchange, relating to the field of oil and gas development. Addressing the difficulty in calculating the pressure within the three media of the matrix zone, weakly stimulated zone, and strongly stimulated zone during shale oil and gas reservoir development, this invention proposes a three-zone average pressure coupling calculation method based on Darcy's law and mass balance. This method fully considers the fluid exchange between the three zones of the shale oil and gas reservoir, utilizing the pressure difference driving mechanism of Darcy's law to directly link pressure changes with fluid flow. It directly couples the pressure of the three zones through fluid exchange, clearly expressing the interaction between each zone, accurately reflecting the influence of pressure gradients and flow fluxes between different areas. It achieves high computational efficiency while ensuring accuracy, not only calculating static pressure distribution but also dynamically tracking pressure changes over time, optimizing oil and gas well production strategies, and improving reservoir development efficiency.

This invention provides a method for predicting the production capacity of electrically heated cold-drive heavy oil reservoirs using wellbore coupling, belonging to the field of oil and gas field development engineering technology. The method includes acquiring basic reservoir parameters and electrical heating parameters; solving for the reservoir temperature distribution at the current time step based on energy conservation; dividing isothermal zones into different temperature zones based on temperature; tracking the cold-drive front position using the Buckley-Leverett method to determine the friction saturation and production end saturation, and calculating the heavy oil production; combining the injection well pressure and friction saturation, solving for the injection-production pressure difference based on Darcy's law to obtain the bottomhole flowing pressure of the production well; inputting the bottomhole flowing pressure and temperature into the wellbore pressure drop model to calculate the wellbore pressure profile and temperature profile; iteratively updating until the end of the production cycle, and outputting the production capacity prediction result. This invention solves the problems of inaccurate predictions caused by existing models' single scenario, neglect of thermal-fluid coupling, and lack of wellbore coupling, and can accurately predict the production capacity of electrically heated assisted cold-drive heavy oil reservoirs.