34 results about "Darcy" patented technology

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 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 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 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 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.

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 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.

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.

The embodiment of the application discloses a kind of well pattern economy evaluation method, device, equipment and medium. Among them, the method comprises: based on Darcy formula, the oil phase seepage velocity of target grid is calculated;According to the oil phase seepage velocity threshold and the oil phase seepage velocity, the target flow speed interval to which the target grid belongs is determined;According to the target speed interval to which each grid belongs, the economic evaluation result of target well pattern is determined.The technical scheme determines the target flow speed interval to which the oil phase seepage velocity of target grid belongs by oil phase seepage velocity threshold, and then determines the economic evaluation result of target well pattern according to the target speed interval to which each grid belongs, the relationship between fluid flow in formation and economic benefit is established in the present scheme, the well pattern is evaluated from the economic point of view, that is, the well pattern control degree is reflected from the economic point of view.

The invention discloses a productivity evaluation method for a small-pressure-difference high-yield gas well, and belongs to the technical field of gas well development, correction coefficients beta corresponding to different alpha coefficients are calculated, and correction coefficient beta charts corresponding to the different alpha coefficients are drawn; the method comprises the following steps: collecting typical gas well productivity well test data, fitting to obtain a Darcy seepage item coefficient A and a non-Darcy seepage item coefficient B, and calculating open flow capacity and a stable empirical number alpha coefficient of a gas well; calculating gas production rates corresponding to different gamma on the basis of formation pressures of gas wells with different stable empirical number alpha coefficients, a Darcy seepage item coefficient A in a pressure square form and a non-Darcy seepage item coefficient B in a gas well pressure form, adding data into the chart, and drawing a'one-point method 'productivity evaluation comprehensive correction chart; and calculating gamma according to the oil testing yield, the formation pressure and the flowing bottomhole pressure of the well, inquiring a correction coefficient beta in the comprehensive correction chart, substituting the correction coefficient beta into a one-point method calculation formula containing the correction coefficient beta, and evaluating the productivity of the gas well.

This invention provides a method and system for calculating inter-well formation pressure after a shale gas platform is put into production. The method includes: calculating the recovery degree R based on EUR and the current cumulative gas production Gp; and calculating the average formation pressure P under the original conditions. i Gas deviation factor Z under original conditions i EUR and Gp are used to calculate P1; a ~R diagram is plotted and a binomial fit is performed to obtain the deviation coefficient σ; P'2 is the measured formation pressure, P'1 is the formation static pressure, Z'1 is the gas deviation factor corresponding to P'1, and Z'2 is the gas deviation factor corresponding to P'2; P2 is calculated based on σ and P1; in the later stage of production, shale gas wells reach the boundary control flow stage, utilizing the formation pressure p at the gas supply boundary. e The Darcy steady-state flow formula for radial flow in a fracturing plane describes the formation pressure p(r) at any distance from the well in the reservoir. The system described above can implement this method. This invention can calculate the formation pressure drop after production commences.

The invention relates to a method for determining a relative permeability curve of ternary composite oil displacement, which comprises the following steps of: establishing a numerical simulation model by using rock core experimental data, and setting a relative permeability curve as uncertain parameter fitting rock core displacement data so as to invert the relative permeability curve of ternary composite oil displacement; the relative permeability curve determined by the method is not limited by the type of the ternary composite solution and is also suitable for a Darcy seepage equation in numerical simulation software, the relative permeability curve is applied to research work in the aspects of reservoir engineering parameter calculation, dynamic analysis, numerical simulation and the like, the accuracy of a research result can be improved, and the research efficiency is improved. The seepage characteristics in the tertiary oil recovery process can be further elaborated, and important technical support is provided for formulating a reasonable working system, optimizing a development scheme and improving the recovery efficiency of tertiary oil recovery.

The invention discloses a method for calculating a permeability coefficient of shield muck under the action of water and soil pressure. The method comprises the following steps: firstly, calculating the porosity of the shield muck under the action of different soil pressure; then considering the plugging effect of foam, and calculating the effective porosity of the shield muck under the effect of water and soil pressure; further, the effective particle size of the shield muck is combined, and the equivalent penetration pipe diameter of the shield muck under the action of water and soil pressure is calculated; and finally, on the basis of a Poiseuille formula and a Darcy law, constructing a shield muck permeability coefficient calculation formula under the action of water and soil pressure. According to the method, the influence of the water and soil pressure on the permeability coefficient of the shield muck can be fully considered, the permeability coefficient obtained through calculation is closer to the actual site situation, and a certain theoretical basis can be provided for shield gushing prevention and control.

The invention relates to a stress sensitivity evaluation method for a shale reservoir with a lamina, which comprises the following steps of: 1, establishing a two-dimensional standard rock core column geometric model with different lamina angles and different lamina thicknesses on the basis of a pore elastic-plastic seepage model; 2, based on geophysical interpretation, literature investigation and laboratory experiments, obtaining geomechanical parameters such as reservoir crustal stress, pore pressure, elastic modulus and Poisson's ratio; 3, different effective confining pressures are applied to the rock core in finite element software, and the change process of ground stress borne by the stratum is simulated; 4, applying seepage pressure difference to the upper end face and the lower end face of the rock core column, and monitoring the total flow flowing out of the end face of the rock core, 5, calculating to obtain the equivalent permeability of the strata-containing shale according to the Darcy law, and 6, drawing a stress sensitivity curve according to the obtained data, and evaluating the stress sensitivity of the strata-containing shale reservoir. And quantitative and accurate evaluation on the reservoir permeability sensitivity of the simulated strata shale reservoir under different effective stress conditions is realized.

The application provides a method for predicting the grouting slurry diffusion range of a coal seam floor area, comprising: obtaining a slurry water displacement model containing minefield stratum parameters and grouting borehole parameters of the coal seam floor area; obtaining a Brinkman equation for describing the incompressible fluid flow caused by reinforcing materials in a porous medium based on the Navier-Stokes equation and the Darcy law; wherein the Brinkman equation contains a viscosity term and a pressure gradient term; taking the grouting pressure, slurry density, dynamic viscosity, porous medium permeability, and porous medium porosity as the influencing factors of slurry diffusion, and obtaining various parameter combinations of each influencing factor and level; using the various parameter combinations, simulating the slurry diffusion process based on the slurry water displacement model by using the Brinkman equation, to obtain the optimal parameter combination and the corresponding slurry diffusion range. The method can scientifically and accurately predict the slurry diffusion range, and improve the consistency and reliability of the grouting treatment effect.

The application discloses a rock specific surface evaluation method based on gas well dynamic data, and comprises the following steps: S1, collecting and arranging gas well static data and gas well dynamic data; S2, using a Blasingame modern production harmonic decline graph board curve to extract a part meeting the Darcy seepage law, and recording a time period as [t0, t1]; S3, calculating an equivalent gas discharge radius and a gas well skin coefficient; selecting a subinterval [t'0, t'1], using an exponential decline model to carry out fitting, and calculating a decline rate; S4, establishing a rock specific surface model, and obtaining the rock specific surface by using the rock specific surface model. The application establishes a quantitative model of the rock specific surface, effectively avoids the limitation of a laboratory overburden condition; meanwhile, by means of well logging interpretation results and seepage mechanics theory, the rock specific surface calculation scale is expanded from a core scale to a large scale of a well logging interpretation series detection radius and a well control range, the rock specific surface model can reduce core analysis experiments, can reduce gas reservoir development cost from the economic aspect, and can improve gas reservoir development benefit.

The invention provides a rock creep model construction method and system based on circulating water flooding-stress coupling, and relates to the technical field of rock mechanics and engineering.The initial physical and mechanical properties of a rock sample are tested through a permeation experiment and a stress permeability experiment, and the moisture permeability and the stress permeability are obtained; the method comprises the following steps: acquiring a covariance matrix of characteristic parameters by utilizing a principal component analysis method, screening out principal components related to moisture and stress permeability, calculating a rock crack sensitivity coefficient and a stress sensitivity coefficient, constructing a moisture migration equation based on a Darcy law, coupling with the sensitivity coefficients to form a rock creep relational expression, and constructing a rock creep prediction model. And performing clustering analysis by using historical data to obtain clustering intervals of different risk levels, and judging the risk level of the rock creep prediction value. According to the method, the creep behavior of the rock in a complex environment is accurately predicted by coupling the moisture permeability and the stress permeability.

A method for determining a relative permeability of a porous medium uses a segmented structural image generated from a 3D image to produce a pore-scale output from a pore-scale flow simulation. A Darcy-scale flow model is generated by simulating fluid flow on boundary conditions of the pore-scale flow simulation and an initial relative permeability model. The Darcy-scale output is compared to the pore-scale output to determine a degree of match. The initial relative permeability model is updated and the Darcy-scale simulation and inverse modeling steps are repeated until the degree of match falls within a pre-determined tolerance.

This invention discloses a method for calculating the production rate of fractured wells in heterogeneous tight oil reservoirs considering the initiation pressure gradient. First, based on the closed boundary point source function, a multi-scale seepage model of matrix seepage in heterogeneous tight oil reservoirs is established using Green's formula and Newman integral. Then, according to the skin principle, a negative skin coefficient is introduced to describe the influence of the fracture network stimulation zone on seepage, resulting in a flow characterization model of the fracture network stimulation zone. Next, the main fracture flow equation is established, and the pressure drop equation of a single discrete fracture unit is described using Darcy's law. The pressure drop characterization model from any discrete unit to the horizontal wellbore is calculated using the pressure drop superposition principle, resulting in the main fracture flow characterization model. Finally, a production rate calculation model for fractured wells in heterogeneous tight oil reservoirs is coupled and established. The steady-state production processes of fracture micro-segments within each small time interval are superimposed, and a heterogeneity coefficient is established based on the skin principle, resulting in a production rate calculation model for fractured wells in heterogeneous tight oil reservoirs under variable production conditions. This method enables rapid and effective, precise prediction of production rates.

The present application provides a kind of shale oil microscale pore nonlinear flow characteristic characterization method, comprising: step 1, the micro-pore structure distribution of shale core is measured;Step 2, the adsorption capacity of shale core to shale oil fluid is measured;Step 3, the micro-pore flow model considering Darcy flow+non-Darcy flow+boundary layer thickness is used, the flow value of shale oil in different size shale pore changes with driving pressure difference is calculated;Step 4, the nonlinear relationship curve of displacement pressure gradient and flow is drawn using the calculation result;Step 5, the nonlinear characteristic parameter of shale oil flowing in different pores of shale is determined according to the nonlinear relationship curve of displacement pressure gradient and flow.The shale oil microscale pore nonlinear flow characteristic characterization method accurately describes the nonlinear flow characteristics of shale oil when passing through the microscale pore space of shale, and provides a reliable theoretical basis for accurately analyzing the nonlinear seepage mechanism of shale oil.

The invention relates to a method and device for calculating the buried height of a blind pipe, and the method comprises the steps: calculating the unit sand amount accumulated in unit time according to the sand removal displacement, the sand removal sand ratio and the apparent density of a proppant; the starting time for starting sand removal and the ending time for ending sand removal are recorded, and the sand removal time is calculated according to the starting time and the ending time; according to the sand removal time and the unit sand amount, the total sand amount accumulated in the annulus between the blind pipe and the casing pipe in the time period is calculated; and calculating the buried height of the blind pipe according to the total sand amount and the density of the proppant body. Compared with the prior art, the method has the advantages that parameters such as proppant permeability and liquid viscosity required by a Darcy formula do not need to be obtained, so that the parameters are easier to obtain, the calculation speed is higher, and the calculation difficulty is reduced while the accuracy is improved.

The invention discloses a porous medium seepage field parameter test model construction method, which comprises the following steps: establishing a three-dimensional underground water flow mathematical model by adopting a Darcy law and a water equilibrium principle, including a partial differential equation for describing the change of an underground water level along with time and an initial boundary condition; calculating an underground water flow field by using GMS software, and obtaining underground water flow field values at different time periods; the vertical strain of the soil body is calculated according to the pressure increment delta P, and the Poisson's ratio, the Biot coefficient and the bulk modulus of the soil body are considered; determining the maximum principal stress and the minimum principal stress according to the calculated effective stress by adopting the Coulomb-Moire criterion, and judging whether the soil body reaches a limit equilibrium state or is damaged or not; calculating the stress strain and the damage state of the soil body through a self-programmed program, and coupling a calculation result with an underground water flow field calculated by GMS software to obtain a prediction result of karst collapse.

The invention provides an underground water flow simulation method for an incomplete well and a related device, and the method comprises the steps: determining the attribute information of non-Darcy seepage of the incomplete well, and carrying out the construction based on the attribute information, and obtaining a fractional order non-Darcy seepage model; analyzing non-darcy seepage based on a fractional order non-darcy seepage model to obtain condition information; analyzing based on the condition information to obtain a time domain analytic solution of non-Darcy seepage; and simulating the water flow of the incomplete well based on the time domain analytical solution to obtain an underground water flow simulation result near the incomplete well. According to the method, the non-Darcy seepage behavior near the incomplete well, especially the flow law under the non-Darcy flow condition, can be accurately described, and the defects of a traditional Darcy law and an integer order derivative model are overcome.

The invention provides a gas reservoir flowing substance equilibrium reserve calculation method, and relates to the technical field of gas reservoir reserve calculation. The method comprises the steps that basic parameters of a constant-volume gas drive gas reservoir and dynamic data of well bottom flowing pressure actually measured in the stable production stage of a gas well are sorted and smoothed; secondly, initial flowing bottomhole pressure and a pressure square difference initial value are determined, and it is assumed that the pressure square difference is constant; then, the average formation pressure, the gas deviation coefficient and the gas isothermal compression coefficient in the gas well stable production process are circularly calculated; then constructing a gas reservoir flowing substance balance equation considering the non-Darcy effect, and calculating dynamic data of variables X and Y; adjusting a pressure square difference value through iteration, and performing linear fitting on the X and Y scatter points until the longitudinal axis intercept of a linear function approaches zero, so as to determine a straight slope; and finally calculating the single well control reserves according to the slope and the basic parameters. According to the method, the limitation of Darcy seepage hypothesis is overcome, and accurate reserve evaluation based on whole-process data is realized.