Method, device and equipment for determining well control reserves of new well commissioning of fractured tight sandstone gas reservoir

Abstract

The invention provides a method, device and equipment for determining well control reserves of a new commissioning well of a fractured tight sandstone gas reservoir, and the method comprises the following steps: 1, recognizing a reservoir flow mode of an old commissioning well, and calculating well control dynamic reserves of the old commissioning well; 2, according to the obtained well control dynamic reserves of the old well commissioning, a relation curve of fracture characteristic parameters, commissioning time and the well control dynamic reserves of the old well commissioning is drawn; step 3, establishing a relation model of the commissioning old well fracture characteristic parameters, the commissioning time and the well control dynamic reserves of different reservoir modes; step 4, identifying a reservoir flow mode of the new commissioning well, and determining fracture characteristic parameters of the new commissioning well; step 5, determining well control reserves of new well commissioning in different commissioning days; the method solves the problem that well control reserves of new wells are difficult to accurately determine when the new wells are put into production for different production days, provides a basis for reasonable technical countermeasure adjustment and development index optimization of gas reservoirs, and has positive significance for improving the development effect and benefit of fractured tight sandstone gas reservoirs.

Description

Technical Field

[0001] The invention belongs to the technical field of oil and gas reservoir development, and in particular relates to a method, a device and equipment for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir. Background Art

[0002] As a clean energy, the demand for natural gas is growing rapidly. As some high-quality gas reservoirs in China have entered the middle and late stages of development, the difficulty of developing natural gas resources is gradually increasing. The quality of new natural gas resources is gradually decreasing, and most of them are deep and complex gas reservoirs, among which fractured tight sandstone gas reservoirs are relatively complex. This type of gas reservoir generally has the characteristics of dense matrix and complex fracture development. The deep fractured tight sandstone gas reservoir in Kuche, Tarim Basin is the most typical. The average porosity of core tests is less than 7%, the permeability is less than 0.1mD, the natural fractures of the reservoir are very developed, and the permeability difference between fractures and matrix reaches three to five orders of magnitude. Due to the dense matrix and complex fracture development, the gas flow in the matrix is ​​in an unstable flow state during the development process, and some of the reserves in the matrix are difficult to mobilize. The well-controlled reserves gradually increase with the development time. Therefore, for new wells put into production, due to the short production time or no production, the well-controlled reserves cannot be accurately determined, which affects the optimization of gas reservoir development indicators and the adjustment of technical countermeasures, and then affects the development effect of new wells. Summary of the invention

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

[0004] In order to achieve the above object, the technical solution adopted by the present invention is:

[0005] The present invention provides a method for determining the well-controlled 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 wells in production and calculating the well-controlled dynamic reserves of the old wells in production;

[0007] Step 2, based on the obtained well-controlled dynamic reserves of the old wells put into production, draw a relationship curve between fracture characteristic parameters, production time and well-controlled dynamic reserves of the old wells put into production;

[0008] Step 3, establishing a relationship model between fracture characteristic parameters, production time and well-controlled dynamic reserves of old wells in different reservoir modes;

[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-controlled reserves of new wells put into production at different production days.

[0011] Preferably, the well-controlled dynamic reserves of the old wells in production are calculated by using the identified reservoir flow pattern of the old wells in production in combination with a modern production decline analysis method.

[0012] Preferably, in step 2, according to the obtained well-controlled dynamic reserves of the old well put into production, a curve of the relationship between the fracture characteristic parameters of the old well put into production, the production time and the well-controlled dynamic reserves is drawn, and the specific method is:

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

[0014] The well-controlled dynamic reserves of the old wells put into production are used as the vertical coordinate to plot the relationship curve between the fracture characteristic parameters of the old wells put into production, the production time and the well-controlled dynamic reserves.

[0015] Preferably, in step 3, a relationship model between fracture characteristic parameters, production time and well-controlled dynamic reserves of old wells in different reservoir modes is established, and the specific method is:

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

[0017] Determine the parameter group of the reservoir flow pattern of the old wells identified in step 1, and combine the obtained parameter group with the reservoir correction coefficient to establish a relationship model between the fracture characteristic parameters, production time and well-controlled reserves of the old wells with different reservoir patterns.

[0018] Preferably, the parameter group of the reservoir flow pattern of the old well identified in step 1 is determined by:

[0019] The parameter cluster of the reservoir flow pattern of the old well identified in step 1 is determined by using water saturation, gas volume coefficient, reservoir matrix porosity, reservoir matrix permeability, gas viscosity and reservoir matrix comprehensive compressibility coefficient.

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

[0021] G gi =α i ×a i ×b fi ×T i +β i

[0022] Among them, G gi is the well-controlled dynamic reserves of the old wells put into production; α i , β i is the correction factor; ai is the parameter group corresponding to the reservoir flow mode; b fi is the fracture characteristic parameter; T is the parameter characterizing the number of days in production; i is the reservoir flow pattern of the identified old well in production.

[0023] Preferably, in step 4, the fracture characteristic parameters of the newly produced well determined are characteristic parameters used to characterize the degree of fracture development.

[0024] Preferably, in step 5, the well-controlled reserves of the new wells put into production at different production days are determined by:

[0025] The fracture characteristic parameters of the newly put into production wells are brought into the fracture characteristic parameters of the old wells put into production of the corresponding reservoir mode, the relationship model between the production time and the well-controlled dynamic reserves, and the well-controlled reserves of the newly put into production wells at different production days are determined.

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

[0027] Well-controlled dynamic reserves calculation unit, used to identify the reservoir flow pattern of old wells in production and calculate the well-controlled dynamic reserves of old wells in production;

[0028] A curve drawing unit is used to draw a curve of the relationship between fracture characteristic parameters, production time and well-controlled reserves of the old wells put into production according to the obtained well-controlled dynamic reserves of the old wells put into production;

[0029] Model building unit, used to establish the relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in different reservoir modes;

[0030] A characteristic parameter determination unit is used to identify the reservoir flow mode of the new well put into production and determine the fracture characteristic parameters of the new well put into production;

[0031] The new well controlled reserves determination unit determines the well controlled reserves of new wells put into production at different production days.

[0032] A device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir comprises a processor and a computer program that can be run on the processor. When the processor executes the computer program, the steps of the method are implemented.

[0033] Compared with the prior art, the present invention has the following beneficial effects:

[0034] The present invention provides a method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir. Based on the characteristics of such gas reservoirs and in combination with the dynamic and static data of existing wells put into production, the well-controlled reserves of the new well put into production can be determined, and then the scale of remaining reserves can be determined, providing a basis for optimizing development indicators and adjusting technical countermeasures, which is of great significance for improving the development effect and benefits of fractured tight sandstone gas reservoirs.

[0035] The method described in the present invention, since the newly put into production wells and the old wells put into production belong to the same block, and the geological background of the gas reservoirs in the same block is similar, the static data (fracture characteristic parameters) and dynamic data (well-controlled reserves) of the old wells put into production in the block are used to establish a correlation (regression model) between the two, and the well-controlled reserves of the newly put into production are predicted by the correlation, because the well-controlled reserves of the newly put into production wells cannot be calculated due to the short production time), but the static data (fracture characteristic parameters) can be obtained by imaging logging and other means; therefore, the present invention can determine the well-controlled reserves of the newly put into production wells of fractured tight sandstone gas reservoirs, solves the problem that it is difficult to accurately determine the well-controlled reserves of the newly put into production wells with different production days, provides a basis for the adjustment of reasonable technical countermeasures for gas reservoirs and the optimization of development indicators, and has positive significance for improving the development effect and benefit of fractured tight sandstone gas reservoirs. BRIEF DESCRIPTION OF THE DRAWINGS

[0036] Figure 1 This is a method flow chart of an implementation method of the method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir provided in the present application.

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

[0038] Figure 3 It is a curve diagram showing the relationship between fracture characteristic parameters of old wells in production, production time and well-controlled reserves in a scenario example using the method for determining well-controlled reserves of new wells in production of fractured tight sandstone gas reservoirs provided by the implementation method of the present application. DETAILED DESCRIPTION

[0039] In the following description, specific details such as specific system structures, technologies, etc. are provided for the purpose of illustration rather than limitation, so as to provide a thorough understanding of the embodiments of the present application. However, it should be clear to those skilled in the art that the present application may also be implemented in other embodiments without these specific details. In other cases, detailed descriptions of well-known systems, devices, circuits, and methods are omitted to prevent unnecessary details from obstructing the description of the present application.

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

[0041] It should also be understood that the term “and / or” used in the specification and appended claims refers to any and all possible combinations of one or more of the associated listed items, and includes these combinations.

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

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

[0044] References to "one embodiment" or "some embodiments" etc. described in the specification of this application mean that one or more embodiments of the present application include specific features, structures or characteristics described in conjunction with the embodiment. Therefore, the statements "in one embodiment", "in some embodiments", "in some other embodiments", "in some other embodiments", etc. that appear in different places in this specification do not necessarily refer to the same embodiment, but mean "one or more but not all embodiments", unless otherwise specifically emphasized in other ways. The terms "including", "comprising", "having" and their variations all mean "including but not limited to", unless otherwise specifically emphasized in other ways.

[0045] Example 1

[0046] A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir provided in an embodiment of the present application may specifically include the following contents:

[0047] S11. Obtain old wells in production with similar geological background to the new well to be put into production, identify the reservoir flow pattern of the old wells in production, and calculate the well-controlled dynamic reserves of the old wells in production.

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

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

[0050] In this embodiment, the well-controlled dynamic reserves of the old wells put into production refer to the natural gas reserves within the pressure wave range caused by the production of the old wells put into production.

[0051] The well-controlled dynamic reserves of the old wells in production are calculated by using the identified reservoir flow patterns and modern production decline analysis methods.

[0052] S12. Draw the relationship curve between fracture characteristic parameters, production time and well-controlled dynamic reserves of old wells put into production.

[0053] In this embodiment, the curve of the relationship between the fracture characteristic parameters of the old well in production, the production time and the well-controlled reserves is drawn, the horizontal axis is the product of the fracture characteristic parameters of the old well in production and the production time, and the vertical axis is the well-controlled dynamic reserves.

[0054] S13, determining the reservoir correction coefficient by performing regression analysis on the relationship curve between fracture characteristic parameters, production time and well-controlled dynamic reserves of the old wells put into production;

[0055] Determine the parameter group corresponding to the reservoir flow mode identified in S11, and combine the obtained parameter group with the reservoir correction coefficient to establish the relationship model between the fracture characteristic parameters, production time and well-controlled dynamic reserves of the old wells in different reservoir modes.

[0056] In this embodiment, the fracture characteristic parameters are fracture parameters interpreted by logging, fracture parameters interpreted by imaging logging, fracture parameters observed by core, or other characteristic parameters characterizing the degree of fracture development.

[0057] The reservoir correction coefficient is determined by regression analysis, and the reservoir correction coefficient α can be determined by linear regression fitting. i , β i The numerical value of .

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

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

[0060]

[0061] In the above formula, S w is 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 comprehensive compressibility coefficient of reservoir matrix; a 1 is the parameter group corresponding to the plane linear flow mode.

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

[0063]

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

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

[0066]

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

[0068] In one embodiment, the establishment of a relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in production with different reservoir flow modes comprises the following steps:

[0069] The relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in production with different reservoir flow modes 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 well-controlled dynamic reserves of the old wells put into production; α i , β i is the correction coefficient, which is related to factors such as reservoir properties and water invasion effects; a i is the reservoir flow pattern parameter group, which is related to the reservoir flow pattern; b fi is the fracture characteristic parameter; T is the parameter characterizing the number of days of production; i represents the reservoir flow mode, such as plane linear flow mode, plane radial flow and vertical fracture well linear flow, including but not limited to these three typical reservoir flow modes.

[0072] When the reservoir flow mode is a plane linear flow mode, t is the number of days to start production.

[0073] When the reservoir flow mode is a planar radial flow mode, T 2 =t.

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

[0075] S14. Identify the reservoir flow pattern of the new well put into production and determine the fracture characteristic parameters of the new well put into production.

[0076] In one embodiment, the identification of the reservoir flow pattern of the new well put into production can be performed by identifying the well test characteristics of the new well put into production. Typical reservoir flow patterns can be divided into planar linear flow patterns, planar radial flows and vertical fracture well linear flows, including but not limited to the above three typical reservoir flow patterns.

[0077] The fracture characteristic parameters of the newly produced well may be fracture parameters interpreted by well logging, fracture parameters interpreted by imaging well logging, fracture parameters observed by cores, or other characteristic parameters characterizing the degree of fracture development of the newly produced well.

[0078] S15, bringing the fracture characteristic parameters of the newly put into production well into the fracture characteristic parameters of the old well put into production in the corresponding reservoir mode, the production time and the well-controlled reserves relationship model, and determining the well-controlled reserves of the newly put into production well at different production days.

[0079] In one embodiment, the fracture characteristic parameters of the newly produced well are brought into the fracture characteristic parameters of the old well in production of the corresponding reservoir mode, the production time and the well-controlled reserves relationship model to determine the well-controlled reserves of the newly produced well at different production days.

[0080] Example 2

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

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

[0083] See also Figure 2 As shown, this embodiment provides a device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir. The device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir can implement the above method, including:

[0084] Well-controlled dynamic reserves calculation unit, used to identify the reservoir flow pattern of old wells in production and calculate the well-controlled dynamic reserves of old wells in production;

[0085] A curve drawing unit is used to draw a curve of the relationship between fracture characteristic parameters, production time and well-controlled reserves of the old wells put into production according to the obtained well-controlled dynamic reserves of the old wells put into production;

[0086] Model building unit, used to establish the relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in different reservoir modes;

[0087] A characteristic parameter determination unit is used to identify the reservoir flow mode of the new well put into production and determine the fracture characteristic parameters of the new well put into production;

[0088] The new well controlled reserves determination unit determines the well controlled reserves of new wells put into production at different production days.

[0089] From the above description, it can be seen that the device for determining the well-controlled reserves of new wells put into production in fractured tight sandstone gas reservoirs provided in the present application fully considers the relationship between the well-controlled reserves of old wells put into production under different reservoir flow patterns, the fracture characteristic parameters, and the number of days put into production through the parameter input module and the model analysis module, introduces regression analysis, and brings the fracture characteristic parameters of the new wells put into production into the relationship model between the fracture characteristic parameters of the old wells put into production in the corresponding reservoir flow pattern, the number of days put into production and the well-controlled reserves, so as to determine the well-controlled reserves of the new wells put into production at different days put into production.

[0090] Example 3

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

[0092] The processor may be a central processing unit (CPU), 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] Example 4

[0094] In a specific implementation scenario, a method and device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir provided by the present application is used to determine the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir. The specific implementation process can refer to the following content:

[0095] S11. Identify the reservoir flow pattern of the old wells in production and calculate the well-controlled dynamic reserves of the old wells in production.

[0096] In this implementation scenario, the well test characteristics of the old wells in production can be used for identification. Typical reservoir flow patterns can be divided into plane linear flow pattern, plane radial flow and vertical fracture well linear flow, etc. Specifically, there are 12 old wells in production in the fractured tight sandstone gas reservoir, and 8 vertical fracture well linear flow pattern wells are identified by well test characteristics.

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

[0098] S12. Draw the relationship curve between fracture characteristic parameters, production time and well-controlled reserves of old wells in production.

[0099] In this implementation scenario, the fracture characteristic parameters may be fracture parameters interpreted by logging, fracture parameters interpreted by imaging logging, fracture parameters observed by cores, or other characteristic parameters characterizing the degree of fracture development.

[0100] In specific implementation, the fracture characteristic parameter is the product of the fracture line density interpreted by imaging logging and the fracture spatial dispersion coefficient. The fracture characteristic parameter values ​​corresponding to the eight 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 relationship between the fracture characteristic parameters of the old well put into production, the time of production and the well-controlled reserves is drawn, the horizontal axis is the product of the fracture characteristic parameters of the old well put into production and the time of production, and the vertical axis is the well-controlled reserves of the old well put into production. Figure 3 The illustrated example is a curve diagram showing the relationship between fracture characteristic parameters of an old well in production, production time and well-controlled reserves, using the method for determining well-controlled reserves of a new well in a fractured tight sandstone gas reservoir provided by an embodiment of the present application in a scenario example.

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

[0103] In this implementation scenario, the reservoir correction coefficient is determined by regression analysis, and the reservoir correction coefficient α can be determined by linear regression fitting. i , β i The numerical value of .

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

[0105]

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

[0107] In this implementation scenario, the reservoir correction coefficient is determined by regression analysis, and the reservoir correction coefficient α can be determined by linear regression fitting. 3 The value of the reservoir correction factor α 3 The value of is 5.87, and the reservoir correction factor β 3 The value of is 4.5. The relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells put into production with different reservoir flow modes is established as follows:

[0108] G g3 =5.87×0.044×b 3i ×T 3 +4.5

[0109] S14. Identify the reservoir flow pattern of the new well put into production and determine the fracture characteristic parameters of the new well put into production.

[0110] In this implementation scenario, the identification of the reservoir flow pattern of the newly put into production well can be identified by the well test characteristics of the newly put into production well. The typical reservoir flow pattern can be divided into a plane linear flow pattern, a plane radial flow and a vertical fracture well linear flow, etc., including but not limited to the above three typical reservoir flow patterns. Specifically, according to the well test characteristics of the newly put into production well A-15, the reservoir flow pattern of the well is identified as a vertical fracture well pattern, and the reservoir flow pattern parameter group value is 0.044.

[0111] The fracture characteristic parameters of the newly put into production well can be the fracture parameters interpreted by logging, fracture parameters interpreted by imaging logging, fracture parameters observed by core or other characteristic parameters characterizing the degree of fracture development of the newly put into production well. Specifically, the fracture characteristic parameters of the newly put into production well are the product of the fracture line density interpreted by imaging logging and the fracture space dispersion coefficient, and the fracture characteristic parameters of the newly put into production well A-15 are 0.19.

[0112] S15, bringing the fracture characteristic parameters of the newly put into production well into the fracture characteristic parameters of the old well put into production in the corresponding reservoir mode, the production time and the well-controlled reserves relationship model, and determining the well-controlled reserves of the newly put into production well at different production days.

[0113] In this implementation scenario, the fracture characteristic parameters of the newly put into production are substituted into the fracture characteristic parameters of the old well put into production of the corresponding reservoir mode, the production time and the well-controlled reserves relationship model, and the well-controlled reserves of the newly put into production at different production days are determined. Specifically, the fracture characteristic parameter 0.19 of the newly put into production well A-15 is substituted into the fracture characteristic parameters of the old well put into production of the corresponding reservoir mode, the production time and the well-controlled reserves relationship model, and it is determined that the well-controlled reserves of the newly put into production well A-15 are 1.04 billion cubic meters at 100 days, 1.47 billion cubic meters at 300 days, and 1.76 billion cubic meters at 500 days.

[0114] The embodiments described above are only used to illustrate the technical solutions of the present application, rather than to limit them. Although the present application has been described in detail with reference to the aforementioned embodiments, a person skilled in the art should understand that the technical solutions described in the aforementioned embodiments may still be modified, or some of the technical features may be replaced by equivalents. Such modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present application, and should all be included in the protection scope of the present application.

Claims

1. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir, characterized in that: The following steps are involved: Step 1, identifying the reservoir flow pattern of the old wells in production and calculating the well-controlled dynamic reserves of the old wells in production; Step 2, based on the obtained well-controlled dynamic reserves of the old wells put into production, draw a curve of the relationship between fracture characteristic parameters, production time and well-controlled reserves of the old wells put into production; Step 3, establishing a relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in different reservoir modes; 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; Step 5, determine the well-controlled reserves of new wells put into production at different production days.

2. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 1, characterized in that: The well-controlled dynamic reserves of the old wells in production are calculated by using the identified reservoir flow patterns and modern production decline analysis methods.

3. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 1, characterized in that: In step 2, according to the obtained well-controlled dynamic reserves of the old wells put into production, a curve of the relationship between the fracture characteristic parameters, production time and well-controlled dynamic reserves of the old wells put into production is drawn. The specific method is: The product of the fracture characteristic parameters of the old wells put into production and the time of production is taken as the horizontal axis; The well-controlled reserves of the old wells put into production are used as the vertical coordinate to plot the relationship curve between the fracture characteristic parameters of the old wells put into production, the production time and the well-controlled dynamic reserves.

4. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 1, characterized in that: In step 3, a relationship model between fracture characteristic parameters, production time and well-controlled dynamic reserves of old wells in different reservoir modes is established. The specific method is: Regression analysis was performed on the relationship curve between fracture characteristic parameters, production time and well-controlled reserves of old wells put into production to determine the reservoir correction coefficient; Determine the parameter group of the reservoir flow pattern of the old wells identified in step 1, and combine the obtained parameter group with the reservoir correction coefficient to establish a relationship model between the fracture characteristic parameters, production time and well-controlled dynamic reserves of the old wells with different reservoir patterns.

5. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 4, characterized in that: Determine the parameter cluster of the reservoir flow pattern of the old well identified in step 1, specifically: The parameter cluster of the reservoir flow pattern of the old well identified in step 1 is determined by using water saturation, gas volume coefficient, reservoir matrix porosity, reservoir matrix permeability, gas viscosity and reservoir matrix comprehensive compressibility coefficient.

6. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 4, characterized in that: The expression of the relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells put into production with different reservoir modes is established as follows: G gi =a i ×a i ×b fi ×T i +b i Among them, G gi is the well-controlled dynamic reserves of the old wells put into production; α i , β i is the correction factor; a i is the parameter group corresponding to the reservoir flow mode; b fi is the fracture characteristic parameter; T is the parameter characterizing the number of days in production; i is the reservoir flow pattern of the identified old well in production.

7. A method for determining the well-controlled reserves of a new well put into production 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 produced well are determined to be characteristic parameters for characterizing the degree of fracture development.

8. A method for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir according to claim 1, characterized in that: In step 5, the well-controlled reserves of the new wells put into production at different production days are determined by: The fracture characteristic parameters of the newly put into production wells are brought into the fracture characteristic parameters of the old wells put into production of the corresponding reservoir mode, the relationship model between the production time and the well-controlled dynamic reserves, and the well-controlled reserves of the newly put into production wells at different production days are determined.

9. A device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir, characterized in that: include: Well-controlled dynamic reserves calculation unit, used to identify the reservoir flow pattern of old wells in production and calculate the well-controlled dynamic reserves of old wells in production; A curve drawing unit is used to draw a curve of the relationship between fracture characteristic parameters, production time and well-controlled reserves of the old wells put into production according to the obtained well-controlled dynamic reserves of the old wells put into production; Model building unit, used to establish the relationship model between fracture characteristic parameters, production time and well-controlled reserves of old wells in different reservoir modes; A characteristic parameter determination unit is used to identify the reservoir flow mode of the new well put into production and determine the fracture characteristic parameters of the new well put into production; The new well controlled reserves determination unit determines the well controlled reserves of new wells put into production at different production days.

10. A device for determining the well-controlled reserves of a new well put into production in a fractured tight sandstone gas reservoir, comprising a processor and a computer program that can be run on the processor, characterized in that: When the processor executes the computer program, the steps of the method according to any one of claims 1 to 8 are implemented.

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