New method and system for numerical simulation history fitting of fractured and porous oil reservoir

Abstract

The invention belongs to the technical field of oil and gas field development engineering, particularly relates to a novel method and system for fracture and pore type reservoir numerical simulation history fitting, and aims at solving the problems that fracture and pore type reservoir numerical simulation history fitting is low in efficiency and poor in precision. The method comprises the following steps: constructing 3D geologic models of different oil reservoir types; initializing each static 3D model to obtain an oil reservoir dynamic model; performing simulation calculation on the oil reservoir dynamic model to obtain a relation equation of water content and recovery percentage of different pore medium reservoirs; constructing a relation chart of the water content and the recovery percentage of the reservoirs with different pore structures; the method comprises the following steps: acquiring relational data of water content and recovery percentage in a production process of an actual production well, matching the relational data with a chart, calculating a decision coefficient of a regression fitting equation of a matched crack-pore structure type, determining the crack-pore structure type of an area where the actual production well is located, and further adjusting historical fitting parameters to realize production historical fitting. According to the method, the efficiency and precision of reservoir numerical simulation history fitting are improved.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas field development engineering technology, specifically relating to a new method and system for numerical simulation history fitting of fractured and porous reservoirs. Background Technology

[0002] Due to the diversity of fracture development and reservoir types, conventional relay-style numerical simulation of reservoirs, such as 3D geological modeling and numerical simulation, will inevitably have certain limitations. The geological modeling-reservoir numerical simulation process should be interactive and combine dynamic and static data to establish a model that accurately reflects production realities. During this process, dynamic data from actual oil and water well production should be used to correct the static parameters of the geological model and improve the accuracy of historical data fitting in the reservoir numerical simulation. Improving the historical data fitting accuracy of numerical simulations for fractured and porous reservoirs is crucial for establishing models that accurately reflect oilfield production realities and remains a challenging area of ​​ongoing research in reservoir engineering. This is especially true for oilfields with a large number of producing wells and long production histories, where historical data fitting is a massive and complex undertaking, requiring significant manpower and time.

[0003] Currently, the main technology involves adjusting fracture parameters to fit the production history. For example, in 1991, Hong Chengxie pointed out in "Application Research of Black Oil Model in Numerical Simulation of Fractured Sandstone Reservoirs" that to study the comprehensive effect of fractures on fluid movement, geological research results can be used as initial values ​​for calculation, and the degree of influence can be determined using dynamic fitting methods. Finally, the development of fractures in the reservoir can be obtained through history fitting. In 1996, Zheng Qiang pointed out in "Discussion on Numerical Simulation Methods for Fractured Reservoirs" that by adjusting parameters such as fracture direction, fracture permeability, and matrix-fracture exchange, single-well injection-production rate, pressure, water cut, production gas-oil ratio, and bottom-hole flowing pressure can be fitted. When the production history fitting results meet the accuracy requirements, the geological model and fracture model are determined.

[0004] However, current numerical simulation history fitting studies of fractured pore reservoirs lack relevant research experience, require high computer performance, involve large investment of manpower and resources, and consume a lot of time. It is difficult to achieve the ideal history fitting effect within a limited time, and it is difficult to guide the development and production of oil fields. Summary of the Invention

[0005] To address the aforementioned problems in the prior art, namely the low efficiency and poor accuracy of history fitting in numerical simulations of fractured-porosity reservoirs, the first aspect of this invention proposes a novel method for history fitting in numerical simulations of fractured-porosity reservoirs, comprising:

[0006] Construct 3D geological models corresponding to different reservoir types as static 3D models;

[0007] The static 3D models are initialized according to the set initialization conditions to obtain the reservoir dynamic model.

[0008] Simulation calculations were performed on reservoir dynamic models corresponding to different reservoir types to obtain equations relating water cut and recovery rate in reservoirs with different porous media.

[0009] Based on the equations relating water cut and recovery rate of reservoirs with different pore media for different reservoir types, a chart of the relationship between water cut and recovery rate of reservoirs with different pore structures is constructed.

[0010] Data on the relationship between water cut and production rate during the actual production process of wells are obtained and matched with the water cut and production rate relationship charts of reservoirs with different pore structures. The determination coefficient of the regression fitting equation of the matched fracture-pore structure type is calculated to determine the fracture-pore structure type of the area where the actual production well is located. Then, the historical fitting parameters are adjusted to achieve production history fitting.

[0011] In some preferred embodiments, the reservoir type includes fracture-pore type, pore type, and fracture type; the fracture-pore structure type includes dual-pore dual-permeability model, single-pore single-permeability model, and dual-pore single-permeability model; the 3D geological model includes structural model, fracture model, net-to-gross ratio model, porosity model, and permeability model.

[0012] In some preferred embodiments, the initialization conditions set include oil-water interpenetration curves, fracture oil-water interpenetration curves, temperature, and pressure.

[0013] In some preferred embodiments, the equations relating water cut and recovery rate of reservoirs with different porosity media corresponding to the fracture type are as follows:

[0014] R = 0.1 * f 0.12 -0.053

[0015] Where R represents the recovery rate and f represents the water content.

[0016] In some preferred embodiments, the equation relating water cut and recovery rate of reservoirs with different pore types is: R = 0.0687 * log(f / (1-f)) + 0.2586.

[0017] In some preferred embodiments, the equation relating water cut and recovery rate of reservoirs with different pore media corresponding to the fracture-pore type is: R = -0.084*log(1-f) + 0.0423.

[0018] In some preferred embodiments, the fracture-pore structure type of the area where the actual production well is located is determined by the following method:

[0019] The water cut and production rate relationship data of the actual production wells during the production process are loaded onto the water cut and production rate relationship charts of reservoirs with different pore structures to obtain preliminary results of the fracture-pore structure type of the area where the actual production wells are located.

[0020] Based on the data on the relationship between water cut and recovery rate during the actual production process of the wells and the preliminary results, the determination coefficient of the regression fitting equation corresponding to the fracture-pore structure type is calculated.

[0021] If the determination coefficient of the regression fitting equation is greater than the set coefficient threshold, then the corresponding fracture-pore structure type is taken as the fracture-pore structure type of the area where the actual production well is located.

[0022] In some preferred embodiments, the determination coefficient of the regression fitting equation corresponding to the crack-pore structure type is calculated by the following method:

[0023]

[0024] Among them, R 2 The coefficient of determination for the regression equation is represented by SSE, the sum of squared residuals is represented by SST, and f is represented by f. i This represents the observed water cut value, specifically the water cut data in the actual production well's data relating water cut to recovery rate, f(r) i ) indicates that when the extraction degree is the observed value r i The corresponding moisture content is calculated at that time, where n represents the number of observations.

[0025] In some preferred embodiments, the historical fitting parameters are adjusted to achieve historical fitting of production, and the method is as follows:

[0026] If the fracture-pore structure type of the area where the actual production well is located is a single-pore single-permeability type, then the porosity and permeability of the fractures are both adjusted to 0, and the production history is fitted by conventional methods.

[0027] If the fracture-pore structure type of the area where the actual production well is located is a dual-pore single-permeability type, then the permeability of the matrix is ​​set to a value less than a set threshold, and the matrix fracture coupling conduction coefficient is adjusted to 0. By adjusting the fracture permeability and combining it with conventional methods, the production history is fitted.

[0028] If the fracture-pore structure type of the area where the actual production well is located is a dual-pore dual-permeability type, then the production history can be fitted by adjusting the fracture permeability, matrix fracture coupling conduction coefficient, and combining conventional methods.

[0029] A second aspect of the present invention proposes a novel system for history fitting in numerical simulation of fractured and porous reservoirs, the system comprising:

[0030] The static model building module is configured to build 3D geological models corresponding to different reservoir types, which are used as static 3D models.

[0031] The dynamic model building module is configured to initialize each static 3D model according to the set initialization conditions to obtain the reservoir dynamic model.

[0032] The equation construction module is configured to simulate and calculate the dynamic models of reservoirs corresponding to different reservoir types, and obtain the equations relating water cut and recovery degree of reservoirs with different porous media.

[0033] The chart construction module is configured to construct charts showing the relationship between water cut and recovery rate in reservoirs with different pore structures based on equations relating water cut and recovery rate in reservoirs with different pore media corresponding to different reservoir types.

[0034] The fitting module is configured to acquire data on the relationship between water cut and production rate during the actual production process of the well, match it with the water cut and production rate relationship charts of reservoirs with different pore structures, calculate the determination coefficient of the regression fitting equation of the matched fracture-pore structure type, determine the fracture-pore structure type of the area where the actual production well is located, and then adjust the historical fitting parameters to achieve production history fitting.

[0035] The beneficial effects of this invention are:

[0036] This invention improves the efficiency and accuracy of reservoir numerical simulation history fitting.

[0037] Based on a theoretical model, this invention effectively matches reservoir production characteristics with fracture and pore types, simulates and calculates theoretical charts for three modes, and calculates the determination coefficient of the regression fitting equation for each type of reservoir to identify the corresponding reservoir type, thereby improving the efficiency and accuracy of reservoir numerical simulation history fitting. Attached Figure Description

[0038] Other features, objects, and advantages of this application will become more apparent from the following detailed description of non-limiting embodiments with reference to the accompanying drawings.

[0039] Figure 1 This is a flowchart illustrating a novel method for history fitting in numerical simulation of fractured and porous reservoirs according to an embodiment of the present invention.

[0040] Figure 2 This is a schematic diagram of the relative permeability curves of oil and water in a matrix system according to an embodiment of the present invention;

[0041] Figure 3 This is a schematic diagram of the relative permeability curves of oil and water in a fracture system according to an embodiment of the present invention;

[0042] Figure 4This is a mesh diagram and permeability contour map of a dual-pore dual-permeability model according to an embodiment of the present invention;

[0043] Figure 5 This is a mesh diagram and permeability contour map of a single-pore single-permeability model according to an embodiment of the present invention;

[0044] Figure 6 This is a mesh diagram and permeability contour map of a dual-pore single-permeability model according to an embodiment of the present invention;

[0045] Figure 7 This is a graph showing the relationship between water cut and recovery rate for three models according to one embodiment of the present invention;

[0046] Figure 8 This is a schematic diagram of the water cut-production degree relationship curve of well P1 according to an embodiment of the present invention;

[0047] Figure 9 This is a schematic diagram of the water cut and recovery rate curve of well P2 according to an embodiment of the present invention;

[0048] Figure 10 This is a schematic diagram of the water cut-production curve of well P3 according to an embodiment of the present invention. Detailed Implementation

[0049] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions in the embodiments of this invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this invention, not all embodiments. Based on the embodiments of this invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this invention.

[0050] The present application will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are for illustrative purposes only and are not intended to limit the invention. Furthermore, it should be noted that, for ease of description, only the parts relevant to the invention are shown in the accompanying drawings.

[0051] It should be noted that, unless otherwise specified, the embodiments and features described in this application can be combined with each other.

[0052] A novel method for history fitting in numerical simulation of fractured and porous reservoirs according to the first embodiment of the present invention, such as... Figure 1 As shown, it includes the following steps:

[0053] Construct 3D geological models corresponding to different reservoir types as static 3D models;

[0054] The static 3D models are initialized according to the set initialization conditions to obtain the reservoir dynamic model.

[0055] Simulation calculations were performed on reservoir dynamic models corresponding to different reservoir types to obtain equations relating water cut and recovery rate in reservoirs with different porous media.

[0056] Based on the equations relating water cut and recovery rate of reservoirs with different pore media for different reservoir types, a chart of the relationship between water cut and recovery rate of reservoirs with different pore structures is constructed.

[0057] Data on the relationship between water cut and production rate during the actual production process of wells are obtained and matched with the water cut and production rate relationship charts of reservoirs with different pore structures. The determination coefficient of the regression fitting equation of the matched fracture-pore structure type is calculated to determine the fracture-pore structure type of the area where the actual production well is located. Then, the historical fitting parameters are adjusted to achieve production history fitting.

[0058] To more clearly illustrate the new method for history fitting in numerical simulation of fractured and porous reservoirs according to the present invention, the steps of one embodiment of the method of the present invention will be described in detail below with reference to the accompanying drawings.

[0059] In fractured-pore reservoirs, the size and distribution of fractures are difficult to determine accurately, and numerical simulation of reservoir production history fitting is a labor-intensive, time-consuming, and complex task. This invention, based on a theoretical model, effectively matches reservoir production characteristics with fracture and pore types, simulates and calculates theoretical charts for three modes, and calculates the determination coefficients of the regression fitting equations for each type of reservoir, thus identifying the corresponding reservoir type and improving the efficiency and quality of reservoir numerical simulation history fitting. Specifically:

[0060] Construct 3D geological models corresponding to different reservoir types as static 3D models;

[0061] Based on the characteristics of fracture and pore development in the reservoir, oil reservoirs are mainly classified into the following three types: fracture-pore type, where fluid flows between matrix and matrix, and between matrix and fracture; pore type, where there are no fractures in the reservoir, and fluid flows only in the pores; and fracture type, where fluid flows only in the fractures, and fluid does not flow in the matrix pores.

[0062] In this embodiment, based on the results of geological research, a 3D geological model is established according to the reservoir structural characteristics, well logging interpretation and core analysis data, reservoir distribution characteristics, fracture characteristics, etc., that is, the 3D geological model corresponding to different reservoir types. The 3D geological model mainly includes structural model, fracture model, net-to-gross ratio model, porosity model, and permeability model.

[0063] The static 3D models are initialized according to the set initialization conditions to obtain the reservoir dynamic model.

[0064] In this embodiment, the 3D geological model is initialized based on the oil-water permeability curves, fracture oil-water permeability curves, initialization conditions such as temperature and pressure, and crude oil PVT data to establish a reservoir dynamic model. For example, in the three models, the production well is P1, the injection well is I1, and the well spacing is 300m. The grid number is 17*14*1, the model grid step size is 25*25m, the formation thickness is 8m, and the net-to-gross ratio is 1. The initial average formation pressure is 19MPa, and there is no edge or bottom water. The relative permeability curves of the matrix system are shown below. Figure 2 (Originally obtained from core waterflooding tests, where Kro represents the relative permeability of the oil phase at different water saturations; Krw represents the relative permeability of the water phase at different water saturations). The relative oil-water permeability curves of the fracture system are shown below. Figure 3 The injection wells inject 80 cubic meters of water per day, and the production wells use constant liquid production with a daily liquid production of 80 cubic meters. The production wells and injection wells perforate the entire oil layer, simulating production for 20 years.

[0065] Simulation calculations were performed on reservoir dynamic models corresponding to different reservoir types to obtain equations relating water cut and recovery rate in reservoirs with different porous media.

[0066] In this embodiment, using established fracture-pore, pore, and fracture models, the reservoir production characteristics of three model types—dual-pore dual-permeability model, single-pore single-permeability model, and dual-pore single-permeability model—are studied. Reservoir numerical simulation is used to calculate indicators such as production and water cut, and equations relating water cut and recovery rate are established for each model.

[0067] The dual-pore dual-permeability model (fracture-pore type, i.e., fracture-pore dual medium), such as Figure 4 As shown in Table 1, the basic physical properties are shown in Table 1. Both the production well and the injection well are located on the fracture zone.

[0068] Table 1

[0069] Single-pore single-permeability model (pore type), such as Figure 5 As shown, the physical properties are shown in Table 2.

[0070] Table 2 property matrix crack Horizontal permeability (mD) 300 / Vertical permeability (mD) 30 / Porosity (%) 22％ / Clean ratio 1 /

[0071] Two-pore single-permeability model (fracture type), such as Figure 6 As shown, the physical properties are shown in Table 3.

[0072] Table 3 property matrix crack Horizontal permeability (mD) 5 2000 Vertical permeability (mD) 0.5 200 Porosity (%) 22％ 0.1％ Clean ratio 1 1

[0073] In all three model modes, based on the initial data described above, the production well P1 is located in the (3, 7) grid, and the water injection well I1 is located in the (15, 7) grid. In the dual-pore dual-permeability model and the dual-pore single-permeability model, both the production well P1 and the water injection well I1 are located on the fracture zone. After well P1 is put into production, well I1 simultaneously begins water injection. Through simulation calculations, the reservoir production characteristics of the three models are as follows.

[0074] Dual-hole single-permeability model (fracture type): The production well has high initial productivity, the earliest water breakthrough, the fastest water cut increase, the shortest stable production period, the lowest cumulative oil production, and the lowest recovery rate. The production well first extracts crude oil from the fractures, and then extracts a small amount of crude oil from the matrix. After water injection, an ineffective cycle between the oil and water wells is easily formed.

[0075] Single-hole single-permeability model (pore type): The oil well has a long stable production period, high cumulative oil production, the highest degree of recovery, the latest water breakthrough time, and a slower increase in water cut, mainly affected by the heterogeneity of the reservoir.

[0076] Dual-pore dual-permeability model (fracture-pore type): The initial production capacity of the oil well is high, and the water breakthrough time is between that of the dual-pore single-permeability model and the single-pore single-permeability model mentioned above. The water cut increases rapidly. After the oil well extracts crude oil from the fractures, it uses the fractures as a seepage channel to extract some crude oil from the matrix. The cumulative oil production and recovery rate are between those of the two models mentioned above.

[0077] The data on the relationship between water cut and recovery rate of reservoirs with different porosity media obtained by simulation calculation using the above model are shown in Table 4.

[0078] Table 4

[0079] Three models were established to establish equations relating water cut to recovery rate:

[0080] Establish the equation relating water cut and production rate in a two-hole single-permeability model (fracture type):

[0081] R = 0.1 * f 0.12 -0.053

[0082] Where R represents the recovery rate, a decimal, generally R∈(0, 0.053); f represents the moisture content, a decimal, generally f∈(0, 0.98).

[0083] Establish the equation relating water cut and recovery rate in a single-hole, single-permeability model (pore type):

[0084] R=0.0687*log(f / (1-f))+0.2586

[0085] Where R represents the recovery rate, a decimal, generally R∈(0, 0.38); f represents the moisture content, a decimal, generally f∈(0, 0.98).

[0086] Establish the equation relating water cut and production rate in a dual-pore dual-permeability model (fracture-pore type):

[0087] R = -0.084 * log(1 - f) + 0.0423

[0088] Where R represents the recovery rate, a decimal, generally R∈(0, 0.184); f represents the moisture content, a decimal, generally f∈(0, 0.98).

[0089] Based on the equations relating water cut and recovery rate of reservoirs with different pore media for different reservoir types, a chart of the relationship between water cut and recovery rate of reservoirs with different pore structures is constructed.

[0090] In this embodiment, a graph showing the relationship between water cut and recovery rate in reservoirs with different pore structures is created, such as... Figure 7 As shown in Table 4, a graph depicting the relationship between water cut and recovery rate in reservoirs with different pore structures can be created.

[0091] Data on the relationship between water cut and production rate during the actual production process of wells are obtained and matched with the water cut and production rate relationship charts of reservoirs with different pore structures. The determination coefficient of the regression fitting equation of the matched fracture-pore structure type is calculated to determine the fracture-pore structure type of the area where the actual production well is located. Then, the historical fitting parameters are adjusted to achieve production history fitting.

[0092] In this embodiment, a combination of static and dynamic methods is used. Actual production data is matched with established charts, and the regression fitting determination coefficients of the corresponding water drive equations are calculated to determine the fracture type. Specifically, based on actual oilfield production, considering well spacing, the area controlled by the well network, and reserves, the controlled reserves of a single well are calculated, along with water cut and recovery rate. Combining production data, the water cut and recovery rate relationship curves for each well are plotted on three different model charts. These curves are then matched with water cut and recovery rate relationship charts for fractured and porous reservoirs in the three models, and the determination coefficients of the regression fitting equations for this type of reservoir are calculated to determine the fracture-pore structure type of the area where the well is located. Finally, based on the matching results of actual production data and the three established model charts, the fracture-pore type of the reservoir is determined, and the fracture-pore structure type of a single well is adjusted to guide the numerical simulation of reservoir production history fitting, improving the accuracy and efficiency of history fitting.

[0093] The relationship between water cut and recovery rate during actual well production is statistically analyzed and calculated. The actual production data is plotted on three model diagrams to preliminarily determine the model type. The determination coefficient of the regression model of this type (i.e., the determination coefficient of the regression fitting equation) is calculated. If the determination coefficient is greater than or equal to the set coefficient threshold (preferably set to 0.8 in this invention), it indicates that the model of this type has a good regression fitting effect with the actual production of the well. Thus, the fracture-pore structure type near the well point is determined.

[0094] This invention selects three typical actual production wells (wells P1, P2, and P3) to calculate the relationship between water cut and recovery rate, as shown in Table 5. The data from Table 5 are then loaded onto the aforementioned graph (…). Figure 7 In the process, it is compared with the illustration. Figure 8 , Figure 9 , Figure 10 ).

[0095] Table 5

[0096] Based on the comparison between the actual production data of well P1 and the relationship chart, it is preliminarily determined that the reservoir in this well area has the characteristics of dual pores and single permeability. The determination coefficient of this type of regression model (i.e., the coefficient of determination of the regression fitting equation) is calculated:

[0097]

[0098] Among them, R 2 The coefficient of determination for the regression equation is represented by SSE, the sum of squared residuals is represented by SST, and f is represented by f. i This represents the observed water cut value, specifically the water cut data in the actual production well's data relating water cut to recovery rate, f(r) i ) indicates that when the extraction degree is the observed value r i The corresponding moisture content is calculated at that time, where n represents the number of observations.

[0099] The determination coefficient R was calculated using the actual production data (water cut and recovery rate observations) from well P1. 2 =0.90, indicating a good regression fit, which determines that the fracture-pore structure type near the well is a dual-pore single-permeability reservoir.

[0100] Based on a comparison of the actual production data and the relationship chart of well P2, it is preliminarily determined that the reservoir in this well area has the characteristics of a dual-pore, dual-permeability reservoir. The determination coefficient of the regression model for this type is calculated. The determination coefficient R is calculated using the actual production data of well P2 (observed values ​​of water cut and recovery rate). 2 =0.85, indicating a good regression fit, which determines that the fracture-pore structure type (or reservoir pore structure type) near the well is a dual-pore dual-permeability reservoir.

[0101] Based on a comparison of the actual production data and the relationship chart of well P3, it is preliminarily determined that the reservoir in this well area has the characteristics of a single-pore, single-permeability reservoir. The determination coefficient of the regression model for this type is calculated. The determination coefficient R is calculated using the actual production data of well P3 (observed values ​​of water cut and recovery rate). 2 =0.88, indicating a good regression fit, which determines that the fracture-pore structure type near the well is a single-pore, single-permeability reservoir.

[0102] By projecting actual production data onto three model diagrams and calculating the coefficient of determination, the reservoir type of the well area is determined when the coefficient of determination is greater than or equal to 0.8. This guides the adjustment of physical property parameters in the history fitting work of numerical simulation of dual-medium reservoirs. For history fitting of production wells belonging to the single-pore, single-permeability type, the porosity and permeability of fractures are adjusted to 0, and the production history is fitted using conventional methods (i.e., adjusting parameters such as permeability, relative permeability data, edge and bottom water volume size and conductivity coefficient, and fault conductivity). For history fitting of production wells belonging to the dual-pore, single-permeability type, the matrix permeability is given a small value (i.e., less than a set threshold value, set according to actual conditions), and the key is to adjust the matrix-fracture coupling conductivity coefficient to 0. Production history fitting is achieved by adjusting fracture permeability and combining it with conventional methods. For history fitting of production wells belonging to the dual-pore, dual-permeability type, production history is achieved by adjusting fracture permeability and matrix-fracture coupling conductivity coefficient (i.e., adjusting fracture permeability, conductivity coefficient, and other fracture-related parameters) and combining it with conventional methods.

[0103] In summary, the method of this invention determines the fracture-pore structure type by analyzing production dynamics, and then adjusts model parameters to achieve history fitting (i.e., based on the theoretical model, it closely links reservoir production characteristics with reservoir development characteristics, classifies reservoirs through theoretical charts and regression equations, clarifies the main controlling factors affecting reservoir production, and conducts targeted parameter adjustment and fitting). Therefore, it improves the scientific nature of history fitting parameter adjustment and the efficiency and accuracy (or quality) of history fitting in numerical simulations of dual-medium reservoirs. This method is more suitable for history fitting research in numerical simulations of dual-medium reservoirs with long development periods.

[0104] A novel system for numerical simulation history fitting of fractured-porosity reservoirs according to a second embodiment of the present invention includes:

[0105] The static model building module is configured to build 3D geological models corresponding to different reservoir types, which are used as static 3D models.

[0106] The dynamic model building module is configured to initialize each static 3D model according to the set initialization conditions to obtain the reservoir dynamic model.

[0107] The equation construction module is configured to simulate and calculate the dynamic models of reservoirs corresponding to different reservoir types, and obtain the equations relating water cut and recovery degree of reservoirs with different porous media.

[0108] The chart construction module is configured to construct charts showing the relationship between water cut and recovery rate in reservoirs with different pore structures based on equations relating water cut and recovery rate in reservoirs with different pore media corresponding to different reservoir types.

[0109] The fitting module is configured to acquire data on the relationship between water cut and production rate during the actual production process of the well, match it with the water cut and production rate relationship charts of reservoirs with different pore structures, calculate the determination coefficient of the regression fitting equation of the matched fracture-pore structure type, determine the fracture-pore structure type of the area where the actual production well is located, and then adjust the historical fitting parameters to achieve production history fitting.

[0110] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the system described above can be found in the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0111] It should be noted that the novel system for numerical simulation and history fitting of fractured and porous reservoirs provided in the above embodiments is only an example of the division of the above functional modules. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the modules or steps in the embodiments of the present invention can be further decomposed or combined. For example, the modules in the above embodiments can be merged into one module, or further divided into multiple sub-modules to complete all or part of the functions described above. The names of the modules and steps involved in the embodiments of the present invention are only for distinguishing the various modules or steps and are not considered as an improper limitation of the present invention.

[0112] A novel device for numerical simulation history fitting of fractured and porous reservoirs according to a third embodiment of the present invention includes: at least one processor; and a memory communicatively connected to at least one of the processors; wherein the memory stores instructions executable by the processor, the instructions being executed by the processor to implement the aforementioned novel method for numerical simulation history fitting of fractured and porous reservoirs.

[0113] A computer-readable storage medium according to a fourth embodiment of the present invention stores computer instructions, which are executed by the computer to implement the above-described novel method for history fitting in numerical simulation of fractured and porous reservoirs.

[0114] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related explanations of the new equipment for historical fitting of numerical simulation of fractured and porous reservoirs described above can be found in the corresponding process in the aforementioned method examples, and will not be repeated here.

[0115] Those skilled in the art will recognize that the modules and method steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, computer software, or a combination of both. The programs corresponding to the software modules and method steps can be placed in random access memory (RAM), main memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disks, removable disks, CD-ROMs, or any other form of storage medium known in the art. To clearly illustrate the interchangeability of electronic hardware and software, the components and steps of the various examples have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in electronic hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of the invention.

[0116] The terms “first,” “second,” “third,” etc., are used to distinguish similar objects, not to describe or indicate a specific order or sequence.

[0117] The technical solution of the present invention has been described above with reference to the preferred embodiments shown in the accompanying drawings. However, it will be readily understood by those skilled in the art that the scope of protection of the present invention is obviously not limited to these specific embodiments. Without departing from the principles of the present invention, those skilled in the art can make equivalent changes or substitutions to the relevant technical features, and the technical solutions after these changes or substitutions will all fall within the scope of protection of the present invention.

Claims

1. A new method for numerical simulation history matching of fractured-porous reservoirs, characterized in that, The method comprises: constructing 3D geological models corresponding to different reservoir types as static 3D models; initializing each static 3D model according to a set initialization condition to obtain a reservoir dynamic model; simulating and calculating the reservoir dynamic models corresponding to different reservoir types to obtain water content and recovery degree relationship equations of different porous media reservoirs; constructing water content and recovery degree relationship charts of different porous structure reservoirs based on the water content and recovery degree relationship equations of different porous media reservoirs corresponding to different reservoir types; obtaining water content and recovery degree relationship data in the production process of an actual production well, matching the data with the water content and recovery degree relationship charts of different porous structure reservoirs, calculating a determination coefficient of a regression fitting equation of a fracture-pore structure type obtained by matching, determining a fracture-pore structure type of a region where the actual production well is located, and then adjusting a history matching parameter to realize production history matching.

2. The new method for numerical simulation history matching of fracture-pore type reservoirs according to claim 1, characterized in that, The reservoir types include fracture-pore type, pore type and fracture type; the fracture-pore structure types include a double-pore double-permeability model, a single-pore single-permeability model and a double-pore single-permeability model; and the 3D geological models include a structure model, a fracture model, a net-to-gross ratio model, a porosity model and a permeability model.

3. A new method for numerical simulation history matching of fractured-porous reservoirs according to claim 2, characterized in that, The set initialization condition includes oil-water relative permeability curves, fracture oil-water relative permeability curves, temperature and pressure.

4. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 3, characterized in that, The water content and recovery degree relationship equation of different porous media reservoirs corresponding to the fracture type is R = -0.084 * log(1-f) + 0.0423, where R represents recovery and f represents water cut. R = 0.1 * f 0.12 -0.053 The water content and recovery degree relationship equation of different porous media reservoirs corresponding to the pore type is R = 0.0687 * log(f / (1-f)) + 0.2586.

5. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 4, characterized in that, The water content and recovery degree relationship equation of different porous media reservoirs corresponding to the fracture-pore type is R = -0.084 * log(1-f) + 0.0423.

6. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 4, characterized in that, The method for determining the fracture-pore structure type of the region where the actual production well is located comprises:

7. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 1, characterized in that, loading water content and recovery degree relationship data in the production process of the actual production well onto each water content and recovery degree relationship chart of different porous structure reservoirs to obtain a preliminary result of the fracture-pore structure type of the region where the actual production well is located; combining the water content and recovery degree relationship data in the production process of the actual production well and the preliminary result to calculate a determination coefficient of a regression fitting equation of a corresponding fracture-pore structure type; if the determination coefficient of the regression fitting equation is greater than a set coefficient threshold, the corresponding fracture-pore structure type is taken as the fracture-pore structure type of the region where the actual production well is located. The method for calculating the determination coefficient of the regression fitting equation of the corresponding fracture-pore structure type comprises:

8. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 7, characterized in that, adjusting a history matching parameter to realize production history matching, and the method comprises: wherein R 2 represents the determination coefficient of the regression fitting equation, SSE represents the residual sum of squares, SST represents the regression sum of squares, f i represents the water cut observation value, i.e. the water cut data in the water cut and recovery degree relationship data in the production process of the actual production well, f(r i ) represents the calculated corresponding water cut when the recovery degree is the observation value r i , and n represents the number of observation values.

9. The new method for numerical simulation history matching of fractured-porous reservoirs according to claim 1, characterized in that, if the fracture-pore structure type of the region where the actual production well is located is a single-pore single-permeability type, the porosity and permeability of the fracture are both adjusted to 0, and a production history is fitted through a conventional method. ​ If the fracture-pore structure type of the area where the actual production well is located is a dual-porosity single-permeability type, the permeability of the matrix is set to a value less than a set threshold, the matrix fracture coupling conductance is adjusted to 0, the fracture permeability is adjusted, and the production history is fitted by combining a conventional method; If the fracture-pore structure type of the area where the actual production well is located is a dual-porosity dual-permeability type, the fracture permeability and the matrix fracture coupling conductance are adjusted, and the production history is fitted by combining a conventional method.

10. A new system for numerical simulation history matching of fractured-porous reservoirs, characterized by, The system comprises: a static model construction module configured to construct 3D geological models corresponding to different reservoir types as static 3D models; a dynamic model construction module configured to initialize each static 3D model according to a set initialization condition to obtain a reservoir dynamic model; an equation construction module configured to simulate and calculate the reservoir dynamic models corresponding to different reservoir types to obtain water cut and recovery degree relationship equations of different porous media reservoirs; a chart construction module configured to construct water cut and recovery degree relationship charts of different porous structure reservoirs based on the water cut and recovery degree relationship equations of different porous media reservoirs corresponding to different reservoir types; a fitting module configured to obtain water cut and recovery degree relationship data in the production process of an actual production well, match the data with the water cut and recovery degree relationship charts of different porous structure reservoirs, calculate the determination coefficient of a regression fitting equation of a matched fracture-pore structure type, determine the fracture-pore structure type of the area where the actual production well is located, and further adjust the history fitting parameters to realize production history fitting.

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