A method, device and equipment for determining well control reserves of a new well put into production in a fractured tight sandstone gas reservoir

Abstract

The application provides a method, device and equipment for determining well control reserves of a new well in a fractured tight sandstone gas reservoir, and comprises the following steps: step 1, identifying a reservoir flow pattern of a production old well, and calculating well control dynamic reserves of the production old well; step 2, drawing a curve of fracture characteristic parameters of the production old well, production time and well control dynamic reserves according to the obtained well control dynamic reserves of the production old well; step 3, establishing a relationship model of fracture characteristic parameters of the production old well, production time and well control dynamic reserves of different reservoir patterns; step 4, identifying a reservoir flow pattern of a production new well, and determining fracture characteristic parameters of the production new well; and step 5, determining well control reserves of the production new well in different production days. The application solves the problem that it is difficult to accurately determine well control reserves of the production new well in different production days, provides a basis for reasonable technical countermeasure adjustment and development index optimization of the gas reservoir, and has a positive significance for improving development effect and benefit of the fractured tight sandstone gas reservoir.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oil and gas reservoir development, and particularly relates to a method, device and equipment for determining well control reserves of a new well put into production in a fractured tight sandstone gas reservoir. BACKGROUND

[0002] Natural gas is a clean energy, and its demand is rapidly increasing. With some high-quality gas reservoirs in China entering the mid-late development stage in succession, the difficulty of natural gas resource development is gradually increasing. New natural gas resources are gradually decreasing in quality, and are mostly deep and complex gas reservoirs, among which the fractured tight sandstone gas reservoir is relatively complex. Such gas reservoirs are generally characterized by tight matrix and complex fracture development, and the Tarim Basin deep fractured tight sandstone gas reservoir is the most typical. The average core test porosity is less than 7%, the permeability is less than 0.1 mD, the natural fractures in the reservoir are very developed, and the permeability ratio of the fractures to the matrix reaches three to five orders of magnitude. Due to the reasons of tight matrix and complex fracture development, the gas flow in the matrix is in an unstable flow state during the development process, and part of the reserves in the matrix is difficult to produce. Therefore, the well control reserves gradually increase with the development time, and thus the well control reserves of the new well put into production cannot be accurately determined due to the short production time or non-production, thereby affecting the optimization of gas reservoir development indexes and the adjustment of technical countermeasures, and further affecting the development effect of the new well. SUMMARY

[0003] The purpose of the present application is to provide a method, device and equipment for determining the well control reserves of a new well put into production in a fractured tight sandstone gas reservoir, and to solve the problem that the well control reserves of the new well put into production in the fractured tight sandstone gas reservoir cannot be determined, resulting in inaccurate optimization of gas reservoir development indexes and adjustment of technical countermeasures.

[0004] In order to achieve the above-mentioned purpose, the technical scheme adopted by the present application is as follows:

[0005] The present application provides a method for determining the well control reserves of a new well put into production in a fractured tight sandstone gas reservoir, comprising the following steps:

[0006] Step 1, identifying the reservoir flow pattern of the old well put into production, and calculating the well control dynamic reserves of the old well put into production;

[0007] Step 2, drawing a curve of the relationship between the fracture characteristic parameters of the old well put into production, the production time and the well control dynamic reserves according to the obtained well control dynamic reserves of the old well put into production;

[0008] Step 3, establishing a relationship model of the fracture characteristic parameters of the old well put into production, the production time and the well control dynamic reserves of different reservoir patterns;

[0009] Step 4, identifying the reservoir flow pattern of the new well put into production, and determining the fracture characteristic parameters of the new well put into production;

[0010] Step 5: Determine the well control reserves of the new wells put into production for different production days.

[0011] Preferably, the well-controlled dynamic reserves of the old wells are calculated by combining the identified reservoir flow patterns with modern production decline analysis methods.

[0012] Preferably, in step 2, based on the obtained well-controlled dynamic reserves of the old wells in production, a curve showing the relationship between fracture characteristic parameters, production time, and well-controlled dynamic reserves of the old wells in production is plotted. The specific method is as follows:

[0013] The product of the fracture characteristic parameters of the old wells put into production and the production time is used as the horizontal axis;

[0014] By plotting the well-controlled dynamic reserves of the old wells in production as the vertical axis, we can obtain the relationship curves between the fracture characteristic parameters of the old wells in production, the production time, and the well-controlled dynamic reserves.

[0015] Preferably, in step 3, a model is established to represent the relationship between fracture characteristic parameters, production time, and well-controlled dynamic reserves of old wells under different reservoir models. The specific method is as follows:

[0016] Regression analysis was performed on the relationship curves between fracture characteristic parameters, production time and well-controlled reserves of old wells in production to determine the reservoir correction coefficient.

[0017] The parameter clusters of the reservoir flow patterns of the old wells identified in step 1 are determined, and the obtained parameter clusters are combined with the reservoir correction coefficients to establish a model of the relationship between fracture characteristic parameters, production time and well-controlled reserves of old wells with different reservoir patterns.

[0018] Preferably, the parameter clusters for determining the reservoir flow patterns of the old wells identified in step 1 are determined by the following method:

[0019] The parameter clusters of the reservoir flow patterns of the old wells identified in step 1 are determined by using water saturation, gas volume factor, reservoir matrix porosity, reservoir matrix permeability, gas viscosity, and reservoir matrix comprehensive compressibility factor.

[0020] Preferably, the expression for establishing the relationship model between fracture characteristic parameters, production time, and well-controlled reserves of old wells with different reservoir modes is as follows:

[0021] G gi =α i ×a i ×b fi ×T i +β i

[0022] Among them, G gi To measure the dynamic reserves of old wells that have been put into production; α i β i This is a correction factor; ai is a parameter corresponding to a reservoir flow pattern; b fi is a fracture characteristic parameter; T is a parameter representing the number of days of production; i is a reservoir flow pattern of the identified production old well.

[0023] Preferably, in step 4, the determined fracture characteristic parameter of the production new well is a characteristic parameter for representing the degree of fracture development.

[0024] Preferably, in step 5, the controlled reserve of the production new well at different production days is determined, and the specific method is:

[0025] The fracture characteristic parameter of the production new well is brought into the fracture characteristic parameter of the production old well corresponding to the reservoir pattern, the production time and the relationship model of the controlled dynamic reserve to determine the controlled reserve of the production new well at different production days.

[0026] A device for determining the controlled reserve of a production new well in a fractured tight sandstone gas reservoir, comprising:

[0027] A controlled dynamic reserve calculation unit for identifying the reservoir flow pattern of the production old well and calculating the controlled dynamic reserve of the production old well.

[0028] A curve drawing unit for drawing a curve of the fracture characteristic parameter of the production old well, the production time and the controlled reserve relationship according to the obtained controlled dynamic reserve of the production old well.

[0029] A model establishment unit for establishing a fracture characteristic parameter of the production old well, a production time and a controlled reserve relationship model of different reservoir patterns.

[0030] A characteristic parameter determination unit for identifying the reservoir flow pattern of the production new well and determining the fracture characteristic parameter of the production new well.

[0031] A new well controlled reserve determination unit for determining the controlled reserve of the production new well at different production days.

[0032] A device for determining the controlled reserve of a production new well in a fractured tight sandstone gas reservoir, comprising a processor and a computer program capable of running on the processor, and the processor executes the computer program to realize the steps of the method.

[0033] Compared with the prior art, the beneficial effects of the present application are:

[0034] The method for determining the controlled reserve of a production new well in a fractured tight sandstone gas reservoir provided by the present application is based on the characteristics of such gas reservoirs, combined with the dynamic and static data of existing production wells, to determine the controlled reserve of the production new well, and then to determine the remaining reserve scale, which provides a basis for development index optimization and technical countermeasure adjustment, and has important significance for improving the development effect and benefit of fractured tight sandstone gas reservoirs.

[0035] The method provided in the present application can determine the well-controlled reserves of the new well of the fractured tight sandstone gas reservoir, and solves the problem that it is difficult to accurately determine the well-controlled reserves of the new well in different production days, provides a basis for rational technical countermeasure adjustment and development index optimization of the gas reservoir, and has a positive significance for improving the development effect and benefit of the fractured tight sandstone gas reservoir. BRIEF DESCRIPTION OF DRAWINGS

[0036] Figure 1 is a method flowchart of one embodiment of the method for determining the well-controlled reserves of the new well of the fractured tight sandstone gas reservoir provided in the present application.

[0037] Figure 2 is a schematic diagram of the device for determining the well-controlled reserves of the new well of the fractured tight sandstone gas reservoir provided in the present application.

[0038] Figure 3 is a curve graph of the relationship between the fracture characteristic parameters of the old well, the production time and the well-controlled reserves of the old well in one scene example of the method for determining the well-controlled reserves of the new well of the fractured tight sandstone gas reservoir provided in the present application. DETAILED DESCRIPTION

[0039] In the following description, specific details are set forth in order to provide a thorough understanding of the embodiments of the present application. However, persons skilled in the art will understand that the present application can be practiced without these specific details. In other instances, well-known structures, devices, circuits, and methods have not been described in detail in order to avoid obscuring the present application.

[0040] It should be understood that, when used in the present application and the appended claims, the term "comprising" indicates the presence of the described features, integers, steps, operations, elements, and / or components, but does not exclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and / or sets thereof.

[0041] It should also be understood that the term "and / or" used in the present application and the appended claims means any combination of the associated listed items and all possible combinations, and includes these combinations.

[0042] As used in the specification and the appended claims, the term "if' can be interpreted as meaning "when" or "upon" or "in response to determining" or "in response to detecting" depending on the context. Similarly, the phrase "if it is determined" or "if [the described condition or event] is detected" can be interpreted to mean "upon determining" or "in response to determining" or "upon detecting [the described condition or event]" or "in response to detecting [the described condition or event]" depending on the context.

[0043] In addition, in the description of the present application and the appended claims, the terms "first", "second", "third", etc. are only used to distinguish the description and cannot be understood as indicating or implying relative importance.

[0044] In the present application, the reference "one embodiment" or "some embodiments" and the like means that the specific features, structures or characteristics described in connection with the embodiment are included in one or more embodiments of the present application. Therefore, the statements "in one embodiment", "in some embodiments", "in other some embodiments", "in further some embodiments" and the like appearing in different places in the specification are not necessarily all referring to the same embodiment, but mean "one or more but not all embodiments", unless otherwise specifically emphasized. The terms "include", "contain", "have" and their variants mean "include but not limited to", unless otherwise specifically emphasized.

[0045] Embodiment 1

[0046] The method for determining the well control reserves of a new well in a fractured tight sand gas reservoir provided by the present application embodiment can specifically include the following contents:

[0047] S11, obtaining a production old well similar to the geological background of the new well to be put into production, identifying the reservoir flow pattern of the production old well, and calculating the well control dynamic reserves of the production old well.

[0048] The new well to be put into production and the production old well belong to the same development block.

[0049] In the present embodiment, the reservoir flow pattern of the production old well is identified by using the well test characteristics of the production old well, wherein the typical reservoir flow patterns include planar linear flow pattern, planar radial flow and vertical fracture well linear flow, etc., including but not limited to the above three typical reservoir flow patterns.

[0050] In the present embodiment, the well control dynamic reserves of the production old well refer to the reserves of natural gas within the pressure wave propagation range caused by the production of the production old well.

[0051] The reservoir flow pattern of the put-into-production old well is identified, and a well-controlled dynamic reservoir volume is calculated by combining a modern production decline analysis method.

[0052] S12, a curve of the fracture characteristic parameter of the put-into-production old well, the production time and the well-controlled dynamic reservoir volume is drawn.

[0053] In the embodiment, the curve of the fracture characteristic parameter of the put-into-production old well, the production time and the well-controlled dynamic reservoir volume has a horizontal coordinate of a product of the fracture characteristic parameter of the put-into-production old well and the production time and a vertical coordinate of the well-controlled dynamic reservoir volume.

[0054] S13, a reservoir correction coefficient is determined by regression analysis on the curve of the fracture characteristic parameter of the put-into-production old well, the production time and the well-controlled dynamic reservoir volume.

[0055] A parameter group corresponding to the reservoir flow pattern identified in S11 is determined, and a relationship model of the fracture characteristic parameter of the put-into-production old well, the production time and the well-controlled dynamic reservoir volume of different reservoir patterns is established by combining the reservoir correction coefficient with the obtained parameter group.

[0056] In the embodiment, the fracture characteristic parameter is a well-logging interpreted fracture parameter, an imaging well-logging interpreted fracture parameter, a core observed fracture parameter or other characteristic parameters representing a fracture development degree.

[0057] The reservoir correction coefficient is determined by regression analysis, and the values of the reservoir correction coefficient α i and β i are determined by linear regression fitting.

[0058] In one embodiment, a parameter group of the reservoir flow pattern of the put-into-production old well identified in step 1 is determined by using the water saturation, the gas volume coefficient, the reservoir matrix porosity, the reservoir matrix permeability, the gas viscosity and the reservoir matrix comprehensive compression coefficient, and specifically:

[0059] The parameter group corresponding to the planar linear flow pattern can be expressed as:

[0060]

[0061] In the above formula, S w is the water saturation; B g is the gas volume coefficient; φ is the reservoir matrix porosity; k m is the reservoir matrix permeability; μ g is the gas viscosity; C gt is the reservoir matrix comprehensive compression coefficient; and a1 is the parameter group corresponding to the planar linear flow pattern.

[0062] The parameter group corresponding to the planar radial flow pattern can be expressed as:

[0063]

[0064] In the above formula, S w is the water saturation; B g is the gas volume factor; μ g is the gas viscosity; C gt is the comprehensive compressibility of the reservoir matrix.

[0065] The parameter group corresponding to the vertical fracture well pattern can be expressed as:

[0066]

[0067] In the above formula, S w is the water saturation; B g is the gas volume factor; μ g is the gas viscosity; C gt is the comprehensive compressibility of the reservoir matrix.

[0068] In one embodiment, the model of the relationship between the fracture characteristic parameters of the producing old well, the production time, and the controlled reserves of the well for different reservoir flow patterns comprises the following steps:

[0069] The model of the relationship between the fracture characteristic parameters of the producing old well, the production time, and the controlled reserves of the well for different reservoir flow patterns is established according to the following formula:

[0070] G gi = α i × a i × b fi × T i + β i

[0071] In the above formula, G gi is the controlled dynamic reserves of the producing old well; α i and β i are correction coefficients, which are related to factors such as reservoir properties and water invasion effects; a i is the parameter group of the reservoir flow pattern, which is related to the reservoir flow pattern; b fi is the fracture characteristic parameter; T is a parameter representing the number of days of production; and i represents the reservoir flow pattern, such as the planar linear flow pattern, the planar radial flow pattern, and the vertical fracture well linear flow pattern, which includes but is not limited to the three typical reservoir flow patterns.

[0072] When the reservoir flow pattern is the planar linear flow pattern, t is the number of days of production.

[0073] When the reservoir flow pattern is the planar radial flow pattern, T2 = t.

[0074] When the reservoir flow pattern is the vertical fracture well pattern,

[0075] S14, identifying a reservoir flow pattern of the new well to be put into production, and determining fracture characteristic parameters of the new well to be put into production.

[0076] In one embodiment, the reservoir flow pattern of the new well to be put into production can be identified by well testing characteristics of the new well to be put into production, and typical reservoir flow patterns can include, but are not limited to, a planar linear flow pattern, a planar radial flow pattern, and a vertical fracture well linear flow pattern.

[0077] The fracture characteristic parameters of the new well to be put into production can be well logging interpreted fracture parameters, imaging logging interpreted fracture parameters, core observation fracture parameters, or other characteristic parameters representing fracture development degrees.

[0078] S15, bringing the fracture characteristic parameters of the new well to be put into production into a model of fracture characteristic parameters of the old well to be put into production, production time, and well-controlled reserve relationship corresponding to the reservoir pattern, to determine well-controlled reserves of the new well to be put into production at different production days.

[0079] In one embodiment, the fracture characteristic parameters of the new well to be put into production are brought into a model of fracture characteristic parameters of the old well to be put into production, production time, and well-controlled reserve relationship corresponding to the reservoir pattern, to determine well-controlled reserves of the new well to be put into production at different production days.

[0080] Embodiment 2

[0081] The embodiment provides a device for determining well-controlled reserves of a new well to be put into production in a fractured tight sandstone gas reservoir, as described in the following embodiments. Since the principle of the device solves the problem is similar to the determination of the well-controlled reserves of the new well to be put into production in the fractured tight sandstone gas reservoir, the implementation of the device for determining the well-controlled reserves of the new well to be put into production in the fractured tight sandstone gas reservoir can be referred to the implementation of the method for determining the well-controlled reserves of the new well to be put into production in the fractured tight sandstone gas reservoir, and the repeated parts will not be described again.

[0082] The term "unit" or "module" used below can be a combination of software and / or hardware that implements a predetermined function. Although the device described in the following embodiments is preferably implemented in software, implementation of hardware, or a combination of software and hardware, is also possible and contemplated.

[0083] Please refer to Figure 2 As shown in the drawings, the device for determining the well-controlled reserves of the new well to be put into production in the fractured tight sandstone gas reservoir provided by the embodiment can implement the above method, and comprises:

[0084] A well-controlled dynamic reserve calculation unit is configured to identify a reservoir flow pattern of the old well to be put into production, and calculate well-controlled dynamic reserves of the old well to be put into production.

[0085] A curve drawing unit is configured to draw a curve of the fracture characteristic parameter of the old well, the production time and the well-controlled reserve according to the obtained well-controlled dynamic reserve of the old well in production.

[0086] A model establishing unit is configured to establish a model of the fracture characteristic parameter of the old well, the production time and the well-controlled reserve of different reservoir modes.

[0087] A characteristic parameter determining unit is configured to identify the reservoir flow mode of the new well in production and determine the fracture characteristic parameter of the new well in production.

[0088] A new well well-controlled reserve determining unit is configured to determine the well-controlled reserve of the new well in production at different production days.

[0089] From the above description, it can be seen that the device for determining the well-controlled reserve of the new well in production of the fractured tight sandstone gas reservoir provided by the application fully considers the relationship between the well-controlled reserve of the old well in production, the fracture characteristic parameter and the production days under different reservoir flow modes through the parameter input module and the model analysis module, introduces regression analysis, brings the fracture characteristic parameter of the new well in production into the model of the fracture characteristic parameter of the old well in production, the production days and the well-controlled reserve of the corresponding reservoir flow mode, and determines the well-controlled reserve of the new well in production at different production days.

[0090] Embodiment 3

[0091] The device for determining the well-controlled reserve of the new well in production of the fractured tight sandstone gas reservoir can be a desktop computer, a notebook computer, a palm computer and a cloud server and the like computing device. The device for determining the well-controlled reserve of the new well in production of the fractured tight sandstone gas reservoir can include, but is not limited to, a processor and a memory.

[0092] The processor can be a central processing unit (CPU), and can also be other general-purpose processors, digital signal processors (DSP), application specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc.

[0093] Embodiment 4

[0094] In a specific implementation scenario, the method and the device for determining the well-controlled reserve of the new well in production of the fractured tight sandstone gas reservoir are applied to determine the well-controlled reserve of the new well in production of a certain fractured tight sandstone gas reservoir, and the specific implementation process can be referred to the following content.

[0095] S11, identify the reservoir flow pattern of the production old well, and calculate the well-controlled dynamic reserves of the production old well.

[0096] In the embodiment, the well test characteristics of the production old well can be used to identify the typical reservoir flow patterns, which can include a planar linear flow pattern, a planar radial flow, and a vertical fracture well linear flow, etc. Specifically, the 12 production old wells of the fractured tight sand gas reservoir are identified as 8 vertical fracture well linear flow patterns by the well test characteristics.

[0097] In the embodiment, the well-controlled dynamic reserves of the production old well are the natural gas reserves within the pressure wave propagation range caused by the production of the production old well, which can be calculated by a modern production decline analysis method. Specifically, the corresponding well-controlled reserves of the 8 vertical fracture well linear flow pattern wells identified by the well test characteristics are 20, 25, 15, 30, 24, 35, 12, and 28 billion cubic meters, respectively. The corresponding production days of the 8 vertical fracture well linear flow pattern wells identified by the well test characteristics are 321, 354, 285, 386, 355, 398, 256, and 335 days, respectively.

[0098] S12, draw a curve of the fracture characteristic parameters, production time, and well-controlled reserves of the production old well.

[0099] In the embodiment, the fracture characteristic parameters can be logging interpretation fracture parameters, imaging logging interpretation fracture parameters, core observation fracture parameters, or other characteristic parameters representing the fracture development degree.

[0100] In the embodiment, the fracture characteristic parameters are the product of the imaging logging interpretation fracture line density and the fracture spatial dispersion coefficient, and the fracture characteristic parameter values of the 8 wells are 0.08, 0.14, 0.05, 0.17, 0.11, 0.24, 0.02, and 0.16, respectively.

[0101] The curve of the fracture characteristic parameters, production time, and well-controlled reserves of the production old well has a horizontal coordinate of the product of the fracture characteristic parameters and the production time of the production old well, and a vertical coordinate of the well-controlled reserves of the production old well. For details, refer to FIG. 2. Figure 3 FIG. 2 shows a curve of the fracture characteristic parameters, production time, and well-controlled reserves of the production old well in one scene example of the method for determining the well-controlled reserves of the production new well of the fractured tight sand gas reservoir according to the embodiment of the application.

[0102] S13, determine a reservoir flow pattern parameter group, determine a reservoir correction coefficient through regression analysis of the curve of the fracture characteristic parameters, production time, and well-controlled reserves of the production old well, and establish a relationship model of the fracture characteristic parameters, production time, and well-controlled reserves of the production old well of different reservoir patterns.

[0103] In the embodiment scenario, the reservoir correction coefficient is determined through regression analysis, and the value of the reservoir correction coefficient a3 can be determined through linear regression fitting. i i

[0104] Specifically, the 8 old production wells are vertical fracture well patterns, and the reservoir flow pattern parameter group can be expressed as:

[0105]

[0106] In the above formula, S w is the water saturation; B g is the gas volume coefficient; μ g is the gas viscosity; and C gt is the comprehensive compressibility of the reservoir matrix.

[0107] In the embodiment scenario, the value of the reservoir correction coefficient a3 can be determined through linear regression fitting, and specifically, the value of the reservoir correction coefficient a3 is 5.87, and the value of the reservoir correction coefficient β3 is 4.5. The relationship model of the fracture characteristics parameters of the old production well, the production time and the controlled reserves of the old production well in different reservoir flow patterns is as follows:

[0108] G g3 = 5.87 x 0.044 x b 3i x T3+ 4.5

[0109] S14, identifying the reservoir flow pattern of the new production well, and determining the fracture characteristics parameters of the new production well.

[0110] In the embodiment scenario, the reservoir flow pattern of the new production well can be identified by the well test characteristics of the new production well. Typical reservoir flow patterns can include, but are not limited to, the above-mentioned three typical reservoir flow patterns. Specifically, according to the well test characteristics of the new production well A-15, it is identified that the reservoir flow pattern of the well is a vertical fracture well pattern, and the value of the reservoir flow pattern parameter group is 0.044.

[0111] The fracture characteristics parameters of the new production well can be the fracture parameters of the well logging interpretation, the fracture parameters of the imaging logging interpretation, the fracture parameters of the core observation, or other characteristic parameters representing the fracture development degree. Specifically, the fracture characteristics parameters of the new production well are the product of the fracture linear density and the fracture spatial dispersion coefficient of the imaging logging interpretation, and the fracture characteristics parameters of the new production well A-15 are 0.19.

[0112] ​​S15, the fracture characteristic parameters of the new well are brought into the model of the fracture characteristic parameters of the old well, the production time and the well-controlled reserves of the corresponding reservoir mode to determine the well-controlled reserves of the new well on different production days.

[0113] In the embodiment scenario, the fracture characteristic parameters of the new well are brought into the model of the fracture characteristic parameters of the old well, the production time and the well-controlled reserves of the corresponding reservoir mode to determine the well-controlled reserves of the new well on different production days. Specifically, the fracture characteristic parameter 0.19 of the new well A-15 is brought into the model of the fracture characteristic parameters of the old well, the production time and the well-controlled reserves of the corresponding reservoir mode to determine that the well-controlled reserves of the new well A-15 is 1.04 billion cubic meters on the 100th day, 1.47 billion cubic meters on the 300th day and 1.76 billion cubic meters on the 500th day.

[0114] The above-described embodiments are only used to illustrate the technical solutions of the present application, rather than limit them; although the present application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that they can still modify the technical solutions recorded in the foregoing embodiments, or make equivalent replacements for some technical features; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the spirit and scope of the technical solutions of the embodiments of the present application, and should be included in the protection scope of the present application.

Claims

1. A method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir, characterized in that, Includes the following steps: Step 1: Identify the reservoir flow patterns of the old wells that have been put into production and calculate the well-controlled dynamic reserves of the old wells that have been put into production; Step 2: Based on the obtained well-controlled dynamic reserves of the old wells in production, plot the relationship curves between fracture characteristic parameters, production time and well-controlled reserves of the old wells in production; Step 3: Establish a model for the relationship between fracture characteristic parameters, production time, and well-controlled reserves of old wells in different reservoir modes; Step 4: Identify the reservoir flow pattern of the newly commissioned well and determine the fracture characteristic parameters of the newly commissioned well; Step 5: Determine the well-controlled reserves of new wells put into production for different production days; In step 2, based on the obtained well-controlled dynamic reserves of the old wells in production, a curve showing the relationship between fracture characteristic parameters, production time, and well-controlled dynamic reserves of the old wells in production is plotted. The specific method is as follows: The product of the fracture characteristic parameters of the old wells put into production and the production time is used as the horizontal axis; By plotting the well-controlled reserves of the old wells in production as the vertical axis, we can obtain the relationship curves between the fracture characteristic parameters of the old wells in production, the production time, and the dynamic reserves controlled by the wells.

2. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 1, characterized in that, The well-controlled dynamic reserves of the old wells were calculated by combining the identified reservoir flow patterns with modern production decline analysis methods.

3. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 1, characterized in that, In step 3, a model is established to represent the relationship between fracture characteristic parameters, production time, and well-controlled dynamic reserves of old wells under different reservoir models. The specific method is as follows: Regression analysis was performed on the relationship curves between fracture characteristic parameters, production time and well-controlled reserves of old wells in production to determine the reservoir correction coefficient. The parameter clusters of the reservoir flow patterns of the old wells identified in step 1 are determined, and the obtained parameter clusters are combined with the reservoir correction coefficients to establish a model of the relationship between fracture characteristic parameters, production time and well-controlled dynamic reserves of old wells with different reservoir patterns.

4. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 3, characterized in that, The specific method for determining the parameter clusters of the reservoir flow pattern of the old wells identified in step 1 is as follows: The parameter clusters of the reservoir flow pattern of the old wells identified in step 1 are determined by using water saturation, gas volume factor, reservoir matrix porosity, reservoir matrix permeability, gas viscosity, and reservoir matrix comprehensive compressibility factor.

5. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 3, characterized in that, The expression for establishing the relationship between fracture characteristic parameters, production time, and well-controlled reserves of old wells with different reservoir models is as follows: in, To determine the dynamic reserves of old wells that have been put into production; , This is a correction factor; These are parameter clusters corresponding to the reservoir flow modes; is the fracture characteristic parameter; T is the parameter characterizing the number of days since production began; i is the reservoir flow pattern of the identified old wells that have been put into production.

6. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 1, characterized in that, In step 4, the obtained fracture characteristic parameters of the newly commissioned well are determined as characteristic parameters used to characterize the degree of fracture development.

7. The method for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir according to claim 1, characterized in that, In step 5, the well-controlled reserves of newly commissioned wells are determined for different production days. The specific method is as follows: The obtained fracture characteristic parameters of the newly put into production wells are input into the fracture characteristic parameters of the old wells put into production in the corresponding reservoir model, the relationship model between production time and well-controlled dynamic reserves, and the well-controlled reserves of the newly put into production wells at different production days are determined.

8. A device for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir, characterized in that, Based on the method of claim 1, the apparatus comprises: The well-controlled dynamic reserves calculation unit is used to identify the reservoir flow patterns of old wells that have been put into production and to calculate the well-controlled dynamic reserves of old wells that have been put into production. The curve plotting unit is used to plot the relationship curves between fracture characteristic parameters, production time and well-controlled reserves of the old wells that have been put into production, based on the obtained well-controlled dynamic reserves of the old wells that have been put into production. The model building unit is used to establish models of the relationship between fracture characteristic parameters, production time and well-controlled reserves of old wells in different reservoir modes. The characteristic parameter determination unit is used to identify the reservoir flow pattern of newly put into production wells and determine the fracture characteristic parameters of newly put into production wells. The new well control reserves determination unit determines the well control reserves of new wells put into production for different production days.

9. An apparatus for determining the well-controlled reserves of a newly commissioned well in a fractured tight sandstone gas reservoir, comprising a processor and a computer program capable of running on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method as described in any one of claims 1-7.

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