Method and system for quantitatively characterizing fracturing effect of high-pressure gas well

Abstract

The invention discloses a method and a system for quantitatively characterizing a fracturing effect of a high-pressure gas well, which are characterized in that a reservoir is evaluated from multiple dimensions by acquiring three key flow data, namely pure matrix open-flow capacity, open-flow capacity before fracturing transformation and open-flow capacity after theoretical fracturing extraction. Calculating the ratio of the natural capacity to the matrix capacity and the ratio of the target capacity to the matrix capacity, and further obtaining the first equivalent fracturing transformation times. And a second equivalent fracturing transformation frequency is also based on the ratio of the target productivity to the matrix productivity. The first equivalent fracturing transformation times and the second equivalent fracturing transformation times are compared, and quantitative characterization of the gas well fracturing effect can be achieved. The quantitative evaluation mode can intuitively tell engineers and researchers that the modification effect of artificial fracturing modification is better, poorer or equivalent compared with the modification effect of reservoir natural fractures. Meanwhile, the quantitative evaluation is also beneficial to comparison among different gas wells, and a basis is provided for selecting a gas well with more potential for development.

Description

Technical Field

[0001] This invention belongs to the field of fracturing technology and relates to a method and system for quantitatively characterizing the fracturing effect of high-pressure gas wells. Background Technology

[0002] Fractured tight sandstone gas reservoirs have a dense matrix and well-developed fractures. Production often falls short of expectations due to formation damage, low formation permeability, low formation pressure, wellbore or tubing blockage, high formation fluid viscosity, excessive bottom-hole back pressure, improper mechanical recovery methods, and other factors. Fracturing increases gas well production by reducing the flow resistance near the wellbore. The resulting sand-filled fractures have a much higher conductivity than the original formation coefficient, significantly increasing the connectivity between the formation and the wellbore. It alters the flow pattern from radial to bilinear, increasing the flow cross-section and reducing flow resistance. It can also connect independent lenses or natural fracture systems, increasing new oil and gas sources. Fractures penetrate the contaminated blockage zone near the wellbore, removing the blockage and thus significantly increasing production.

[0003] Existing technologies propose a method and apparatus for evaluating fracturing effectiveness. This method determines fracturing implementation effectiveness evaluation indicators based on fracturing design data and field implementation data; it evaluates the fracturing effect based on both the fracturing production enhancement effect evaluation indicators and the fracturing implementation effect evaluation indicators, thereby improving the accuracy of fracturing effectiveness evaluation. Another method and apparatus for evaluating formation hydraulic fracturing effectiveness involves array acoustic logging within a depth range to construct dipole acoustic logging data from different azimuths. This data is then filtered and normalized to calculate the energy envelope of scattered waves before and after fracturing. The difference in shear wave velocity and scattered wave energy between the pre- and post-fracturing dipole acoustic logging data is used to jointly evaluate the wellbore fracturing effect. A method for predicting production and evaluating fracturing effectiveness in unconventional oil and gas wells utilizes a fracturing flowback history analysis module to leverage post-fracturing flowback data that is often overlooked in the field, evaluating the initial effective pore volume and fracture volume loss rate, among other things.

[0004] Currently, most evaluations of fracturing effectiveness focus on assessing fracturing-induced production increases using relevant indicators. Existing assessment techniques are qualitative or semi-quantitative, offering limited guidance for process selection and failing to quantitatively characterize the fracturing effect in high-pressure gas wells. Therefore, in-depth research into methods for quantitatively characterizing the fracturing effect in high-pressure gas wells has significant research and application value. Summary of the Invention

[0005] The purpose of this invention is to solve the problem that the fracturing effect of high-pressure gas wells cannot be quantitatively characterized in the prior art, and to provide a method and system for quantitatively characterizing the fracturing effect of high-pressure gas wells.

[0006] To achieve the above objectives, the present invention employs the following technical solution:

[0007] This invention proposes a method for quantitatively characterizing the fracturing effect of high-pressure gas wells, comprising:

[0008] Obtain the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase;

[0009] The ratio of natural production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing modification; the ratio of target production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase.

[0010] The equivalent wellbore radius of natural fractures for wellbore modification is obtained based on the ratio of natural production capacity to matrix production capacity, and the first equivalent fracturing stimulation number is obtained based on the equivalent wellbore radius of natural fractures for wellbore modification.

[0011] The equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity, and the second equivalent fracturing number of times is obtained based on the equivalent wellbore radius after fracturing.

[0012] By comparing the number of fracturing operations in the first equivalent manner and the number of fracturing operations in the second equivalent manner, a quantitative characterization of the fracturing effect of gas wells can be achieved.

[0013] Preferably, obtaining the unobstructed flow rate of the pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase specifically involves:

[0014] Pure matrix unobstructed flow

[0015] Unrestricted flow rate before fracturing

[0016] Theoretical unobstructed flow rate after fracturing to increase production

[0017] Where k is the absolute permeability of the formation, h is the formation thickness, and T is the density of the formation. sc For the standard condition temperature, Z sc P is the gas deviation factor under standard conditions. i Where P is the original formation pressure, T is the reservoir temperature, and P is the gas reservoir temperature. sc The gas pressure under standard conditions, μ i Z represents the gas viscosity under original gas reservoir conditions. i r is the gas deviation factor under the original gas reservoir conditions. e r is the gas reservoir outflow radius. w Where π is the wellbore radius, π is a mathematical constant, and ΔP is the reservoir boundary pressure P. e With bottom hole pressure P wf The difference, r w "r" represents the equivalent wellbore radius after theoretical fracturing. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.'

[0018] Preferably, the step of obtaining the ratio of natural production capacity to matrix production capacity based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate before fracturing modification specifically involves:

[0019]

[0020] Among them, FOI nf r is the ratio of natural production capacity to substrate production capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.'

[0021] Preferably, the step of obtaining the target production capacity to matrix production capacity ratio based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate after theoretical fracturing production increase specifically involves:

[0022]

[0023] Among them, FOI fac r is the ratio of target capacity to substrate capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w "This is the equivalent wellbore radius after theoretical fracturing."

[0024] Preferably, the step of obtaining the equivalent wellbore radius for wellbore modification based on the ratio of natural productivity to matrix productivity specifically involves:

[0025]

[0026] Where, r w1 ' is the equivalent wellbore radius due to natural fractures, n1 is the first equivalent fracturing stimulation number, x f Where is the productivity coefficient and P is the formation pressure.

[0027] Preferably, the equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity, specifically as follows:

[0028]

[0029] Where, r w1 " is the equivalent wellbore radius after fracturing, n2 is the first equivalent fracturing stimulation number, x" f Where is the productivity coefficient and P is the formation pressure.

[0030] This invention proposes a method for quantitatively characterizing the fracturing effect of high-pressure gas wells, comprising:

[0031] The first data acquisition module is used to acquire the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the unobstructed flow rate after theoretical fracturing production increase.

[0032] The second data acquisition module is used to obtain the ratio of natural production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing; and to obtain the ratio of target production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase.

[0033] The first fracturing number acquisition module is used to obtain the equivalent wellbore radius of natural fractures on wellbore modification based on the ratio of natural production capacity to matrix production capacity, and to obtain the first equivalent fracturing number based on the equivalent wellbore radius of natural fractures on wellbore modification.

[0034] The second fracturing number acquisition module is used to obtain the equivalent wellbore radius after fracturing based on the ratio of target production capacity to matrix production capacity, and to obtain the second equivalent fracturing number based on the equivalent wellbore radius after fracturing.

[0035] The comparison module is used to compare the first equivalent fracturing stimulation number and the second equivalent fracturing stimulation number to achieve a quantitative characterization of the fracturing effect of the gas well.

[0036] A terminal device includes a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of a method for quantitatively characterizing the fracturing effect of a high-pressure gas well.

[0037] A computer-readable storage medium storing a computer program, which, when executed by a processor, implements the steps of a method for quantitatively characterizing the fracturing effect of a high-pressure gas well.

[0038] A computer program product includes a computer program that, when executed by a processor, implements the steps of a method for quantitatively characterizing the fracturing effect of a high-pressure gas well.

[0039] Compared with the prior art, the present invention has the following beneficial effects:

[0040] This invention proposes a method for quantitatively characterizing the fracturing effect of high-pressure gas wells. It obtains three key flow data points: unobstructed flow rate in the pure matrix, unobstructed flow rate before fracturing, and unobstructed flow rate after theoretical fracturing production enhancement. Combining these three data points provides a more comprehensive understanding of the reservoir's productivity characteristics and allows for reservoir evaluation from multiple dimensions. Calculating the ratio of natural productivity to matrix productivity and the ratio of target productivity to matrix productivity clearly distinguishes between natural productivity enhancement and productivity enhancement after artificial fracturing. The natural productivity to matrix productivity ratio can be used to analyze the degree of wellbore modification by natural fractures, quantifying this natural modification effect with an equivalent wellbore radius, thus obtaining the first equivalent number of fracturing operations. This is equivalent to equating the modification effect of natural fractures to the number of artificial fracturing operations, facilitating comparison. Similarly, the target productivity to matrix productivity ratio can analyze the effect after artificial fracturing, obtaining the equivalent wellbore radius and the second equivalent number of fracturing operations, thereby clarifying the specific contribution of artificial fracturing to reservoir productivity enhancement. Comparing the first and second equivalent fracturing stimulation times allows for a quantitative characterization of the fracturing effect in gas wells. This quantitative assessment method can intuitively tell engineers and researchers whether artificial fracturing is better, worse, or comparable to the stimulation of natural reservoir fractures. Furthermore, this quantitative assessment facilitates comparisons between different gas wells, providing a basis for selecting wells with greater development potential.

[0041] This invention proposes a system for quantitatively characterizing the fracturing effect of high-pressure gas wells. By dividing the system into a first data acquisition module, a second data acquisition module, a first fracturing frequency acquisition module, a second fracturing frequency acquisition module, and a comparison module, the system achieves quantitative characterization of the gas well fracturing effect. The modular approach ensures that each module is independent, facilitating unified management of all modules. Attached Figure Description

[0042] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0043] Figure 1 This is a flowchart of the method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to the present invention.

[0044] Figure 2 This is a schematic diagram of the equivalent radius of the present invention.

[0045] Figure 3 This is a system diagram illustrating the quantitative characterization of the fracturing effect of high-pressure gas wells according to the present invention.

[0046] Figure 4 This is a schematic diagram of the structure of an electronic device according to the present invention. Detailed Implementation

[0047] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. The components of the embodiments of the present invention described and shown in the accompanying drawings can generally be arranged and designed in various different configurations.

[0048] Therefore, the following detailed description of the embodiments of the invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments of the invention. All other embodiments obtained by those skilled in the art based on the embodiments of the invention without inventive effort are within the scope of protection of the invention.

[0049] It should be noted that similar labels and letters in the following figures indicate similar items. Therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures.

[0050] In the description of the embodiments of the present invention, it should be noted that if terms such as "upper," "lower," "horizontal," or "inner" indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, or the orientation or positional relationship commonly used when the product of the invention is in use, they are only for the convenience of describing the present invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the present invention. Furthermore, terms such as "first" and "second" are only used to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0051] Furthermore, the use of the term "horizontal" does not imply that the component must be absolutely horizontal, but rather that it can be slightly tilted. For example, "horizontal" simply means that its direction is more horizontal than "vertical," and does not mean that the structure must be completely horizontal, but can be slightly tilted.

[0052] In the description of the embodiments of the present invention, it should also be noted that, unless otherwise explicitly specified and limited, the terms "set," "install," "connect," and "link" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in the present invention according to the specific circumstances.

[0053] The present invention will now be described in further detail with reference to the accompanying drawings:

[0054] Example 1

[0055] This invention proposes a method for quantitatively characterizing the fracturing effect of high-pressure gas wells, such as... Figure 1 As shown, it includes:

[0056] S1. Obtain the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase;

[0057] The acquisition of the unobstructed flow rate of the pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase are specifically as follows:

[0058] Pure matrix unobstructed flow

[0059] Unrestricted flow rate before fracturing

[0060] Theoretical unobstructed flow rate after fracturing to increase production

[0061] Where k is the absolute permeability of the formation, h is the formation thickness, and T is the density of the formation. sc For the standard condition temperature, Z sc P is the gas deviation factor under standard conditions. i Where P is the original formation pressure, T is the reservoir temperature, and P is the gas reservoir temperature. sc The gas pressure under standard conditions, μ i Z represents the gas viscosity under original gas reservoir conditions. i r is the gas deviation factor under the original gas reservoir conditions. e r is the gas reservoir outflow radius. w Where π is the wellbore radius, π is a mathematical constant, and ΔP is the reservoir boundary pressure P. e With bottom hole pressure P wf The difference, r w "r" represents the equivalent wellbore radius after theoretical fracturing. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.'

[0062] S2. Obtain the ratio of natural production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing modification; obtain the ratio of target production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase.

[0063] The ratio of natural productivity to matrix productivity is obtained based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate before fracturing modification, specifically as follows:

[0064]

[0065] Among them, FOI nf r is the ratio of natural production capacity to substrate production capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.'

[0066] The ratio of target production capacity to matrix production capacity is obtained based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate after theoretical fracturing production increase, specifically as follows:

[0067]

[0068] Among them, FOI fac r is the ratio of target capacity to substrate capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w "This is the equivalent wellbore radius after theoretical fracturing."

[0069] S3. Obtain the equivalent wellbore radius of natural fractures for wellbore modification based on the ratio of natural production capacity to matrix production capacity, and obtain the first equivalent fracturing stimulation number based on the equivalent wellbore radius of natural fractures for wellbore modification.

[0070] The method for obtaining the equivalent wellbore radius for wellbore modification based on the ratio of natural productivity to matrix productivity is as follows:

[0071]

[0072] Where, r w1 ' is the equivalent wellbore radius due to natural fractures, n1 is the first equivalent fracturing stimulation number, x f This represents the production capacity coefficient.

[0073] S4. Obtain the equivalent wellbore radius after fracturing based on the ratio of target production capacity to matrix production capacity, and obtain the second equivalent fracturing stimulation number based on the equivalent wellbore radius after fracturing stimulation.

[0074] The equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity. Specifically:

[0075]

[0076] Where, r w1 " is the equivalent wellbore radius after fracturing, n2 is the first equivalent fracturing stimulation number, x" f This represents the production capacity coefficient.

[0077] S5. Compare the first equivalent fracturing stimulation number and the second equivalent fracturing stimulation number to achieve a quantitative characterization of the fracturing effect of the gas well.

[0078] The method is described in detail below:

[0079] 1) Calculate the unobstructed flow rate q of the pure matrix using reservoir pressure, reservoir temperature, reservoir condition volume factor, and well logging interpretation permeability. o Based on the production data from the pre-fracturing blowout test, the unobstructed flow rate q before fracturing was calculated using a single-point method, including oil pressure and daily gas production. nf The corresponding unobstructed flow rate q is calculated based on the binomial parameter energy formula fitted after fracturing, thus obtaining the theoretical unobstructed flow rate q after fracturing production increase. fac .

[0080] Gas production formula:

[0081] 2) The stimulation of the reservoir by natural fractures is equivalent to the fixed length (100m) and fixed height (50m) hydraulic fractures. The intensity of the stimulation of the reservoir by natural fractures and its impact on production capacity are measured by the equivalent number of hydraulic fractures, i.e. the relationship between the number of stimulations n1 and the ratio of natural production capacity to matrix production capacity.

[0082]

[0083] 3) The total number of modifications n2 under the superposition effect of artificial cracks (crack length 100m, crack height 50m) and natural cracks is related to the ratio of target capacity to natural capacity to matrix capacity.

[0084]

[0085] Comparing the data of n2 and n1, n1 represents the equivalent number of fracturing operations due to the natural fractures in the reservoir itself, which is recorded as the first equivalent number of fracturing operations. n2 represents the equivalent number of fracturing operations due to the natural fractures in the reservoir itself plus the artificial fractures after fracturing, which is recorded as the second equivalent number of fracturing operations. The difference between them represents the increase in the equivalent radius of the high-pressure gas well's production capacity.

[0086] In the above scheme, the Using FOI nf This means that its physical meaning is natural production capacity / matrix production capacity, which is easy to obtain, and the production increase ratio depends on the number of times the natural fractures have equivalently modified the reservoir, n1.

[0087] In the above scheme, the Using FOI fac This means that its physical meaning is the post-press capacity (target output) / substrate capacity, and the size of the production increase ratio depends on the operational capacity and segmentation capacity n2.

[0088] In the above scheme, the equivalent number of fracturing operations is to equate the modification of the reservoir by natural fractures to a fixed length (100m) and a fixed height (50m) fracturing operation as the standard value for one fracturing operation. This method assumes that all fracturing depths are fixed lengths (100m).

[0089] In the above scheme, by The equivalent wellbore radius r of the natural fracture for wellbore modification can be obtained. w ',Depend on Get the value of n1.

[0090] In the above scheme, by The equivalent wellbore radius r after fracturing can be obtained. w ",Depend on Get the value of n2.

[0091] Taking well K6 as an example, the basic information of a method for quantitatively characterizing the fracturing effect of high-pressure gas wells is shown in the table below:

[0092]

[0093]

[0094] Includes the following steps:

[0095] (1) Matrix productivity: reservoir pressure 96.91 MPa, reservoir temperature 141.7℃, reservoir condition volume factor 2.473×10 -3 With a well logging interpretation permeability of 0.2 mD, the calculated pure matrix free flow rate is 6.4 × 10⁻⁶. 4 m 3 / d;

[0096] (2) Natural production capacity: 4mm nozzle release, oil pressure 22.42↓20.284MPa, equivalent to daily gas production of 16.6×10 4 m 3 / d, the unobstructed flow rate calculated using the one-point method is 18.13 × 10⁻⁶. 4 m 3 / d.

[0097] (3) Post-fracturing production capacity: According to the "Analysis Report on Production Capacity Testing of Keshen 605", the binomial parameter energy formula fitted after fracturing is (unrestricted flow rate) 217.28 × 10 4 m 3 / d, theoretical unobstructed flow rate after fracturing and production increase: 36×10 4 m 3 / d, it is speculated that the fracturing of this well connected the natural fracture in the distant well.

[0098] (4) Calculate the ratio of the number of modifications n1 to the natural production capacity and the substrate production capacity:

[0099] (5) Calculate the equivalent wellbore radius for wellbore modification due to natural fractures: r w =4.29m.

[0100] (6) Calculate n1:

[0101] (7) Calculate the relationship between the total number of renovations n2 and the expected target (planned capacity) and the substrate capacity:

[0102]

[0103] (8) Calculate the equivalent wellbore radius after fracturing: r w =336m.

[0104] (9) Calculate n²:

[0105] (10) The result of this modification was n2-n1=5.27-0.07=5.2, indicating that the fracturing measures were effective. The fracturing connected the natural fractures in the distant well, achieving the goal of quantitatively characterizing the fracturing effect of high-pressure gas wells. Figure 2 The diagram shown is a schematic of the equivalent radius.

[0106] Example 2

[0107] This invention proposes a method for quantitatively characterizing the fracturing effect of high-pressure gas wells, such as... Figure 3 As shown, it includes:

[0108] The first data acquisition module is used to acquire the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the unobstructed flow rate after theoretical fracturing production increase.

[0109] The second data acquisition module is used to obtain the ratio of natural production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing; and to obtain the ratio of target production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase.

[0110] The first fracturing number acquisition module is used to obtain the equivalent wellbore radius of natural fractures on wellbore modification based on the ratio of natural production capacity to matrix production capacity, and to obtain the first equivalent fracturing number based on the equivalent wellbore radius of natural fractures on wellbore modification.

[0111] The second fracturing number acquisition module is used to obtain the equivalent wellbore radius after fracturing based on the ratio of target production capacity to matrix production capacity, and to obtain the second equivalent fracturing number based on the equivalent wellbore radius after fracturing.

[0112] The comparison module is used to compare the first equivalent fracturing stimulation number and the second equivalent fracturing stimulation number to achieve a quantitative characterization of the fracturing effect of the gas well.

[0113] Example 3

[0114] Please see Figure 4 As shown, the present invention also provides an electronic device 100 for a method of quantitatively characterizing the fracturing effect of high-pressure gas wells; the electronic device 100 includes a memory 101, at least one processor 102, a computer program 103 stored in the memory 101 and executable on the at least one processor 102, and at least one communication bus 104.

[0115] The memory 101 can be used to store the computer program 103. The processor 102 implements the steps of the method for quantitatively characterizing the fracturing effect of high-pressure gas wells as described in Embodiment 1 by running or executing the computer program stored in the memory 101 and calling the data stored in the memory 101. The memory 101 may mainly include a program storage area and a data storage area. The program storage area may store the operating system, at least one application program required for a function (such as sound playback function, image playback function, etc.), etc.; the data storage area may store data created according to the use of the electronic device 100 (such as audio data), etc. In addition, the memory 101 may include non-volatile memory, such as hard disk, memory, plug-in hard disk, smart media card (SMC), secure digital (SD) card, flash card, at least one disk storage device, flash memory device, or other non-volatile solid-state storage device.

[0116] The at least one processor 102 may be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The processor 102 may be a microprocessor or any conventional processor. The processor 102 is the control center of the electronic device 100, connecting various parts of the electronic device 100 via various interfaces and lines.

[0117] The memory 101 in the electronic device 100 stores multiple instructions to implement a method for quantitatively characterizing the fracturing effect of a high-pressure gas well, and the processor 102 can execute the multiple instructions to achieve the following:

[0118] Obtain the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase;

[0119] The ratio of natural production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing modification; the ratio of target production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase.

[0120] The equivalent wellbore radius of natural fractures for wellbore modification is obtained based on the ratio of natural production capacity to matrix production capacity, and the first equivalent fracturing stimulation number is obtained based on the equivalent wellbore radius of natural fractures for wellbore modification.

[0121] The equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity, and the second equivalent fracturing number of times is obtained based on the equivalent wellbore radius after fracturing.

[0122] By comparing the number of fracturing operations in the first equivalent manner and the number of fracturing operations in the second equivalent manner, a quantitative characterization of the fracturing effect of gas wells can be achieved.

[0123] Example 4

[0124] If the modules / units integrated in the electronic device 100 are implemented as software functional units and sold or used as independent products, they can be stored in a computer-readable storage medium. Based on this understanding, all or part of the processes in the methods of the above embodiments can also be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include: any entity or device capable of carrying the computer program code, a recording medium, a USB flash drive, a portable hard drive, a magnetic disk, an optical disk, a computer memory, and a read-only memory (ROM).

[0125] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0126] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0127] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0128] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0129] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the specific implementation of the present invention. Any modifications or equivalent substitutions that do not depart from the spirit and scope of the present invention should be covered within the scope of protection of the claims of the present invention.

Claims

1. A method for quantitatively characterizing the fracturing effect of high-pressure gas wells, characterized in that, include: Obtain the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase; The ratio of natural production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing modification; the ratio of target production capacity to matrix production capacity is obtained based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase. The equivalent wellbore radius of natural fractures for wellbore modification is obtained based on the ratio of natural production capacity to matrix production capacity, and the first equivalent fracturing stimulation number is obtained based on the equivalent wellbore radius of natural fractures for wellbore modification. The equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity, and the second equivalent fracturing number of times is obtained based on the equivalent wellbore radius after fracturing. By comparing the number of fracturing operations in the first equivalent manner and the number of fracturing operations in the second equivalent manner, a quantitative characterization of the fracturing effect of gas wells can be achieved.

2. The method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to claim 1, characterized in that, The acquisition of the unobstructed flow rate of the pure matrix, the unobstructed flow rate before fracturing modification, and the theoretical unobstructed flow rate after fracturing production increase are specifically as follows: Pure matrix unobstructed flow Unrestricted flow rate before fracturing Theoretical unobstructed flow rate after fracturing to increase production Where k is the absolute permeability of the formation, h is the formation thickness, and T is the density of the formation. sc For the standard condition temperature, Z sc P is the gas deviation factor under standard conditions. i Where P is the original formation pressure, T is the reservoir temperature, and P is the gas reservoir temperature. sc The gas pressure under standard conditions, μ i Z represents the gas viscosity under original gas reservoir conditions. i r is the gas deviation factor under the original gas reservoir conditions. e r is the gas reservoir outflow radius. w Where π is the wellbore radius, π is a mathematical constant, and ΔP is the reservoir boundary pressure P. e With bottom hole pressure P wf The difference, r w "r" represents the equivalent wellbore radius after theoretical fracturing. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.' 3. The method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to claim 1, characterized in that, The ratio of natural productivity to matrix productivity is obtained based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate before fracturing modification, specifically as follows: Among them, FOI nf r is the ratio of natural production capacity to substrate production capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w 'The equivalent wellbore radius for theoretical natural fractures in wellbore modification.' 4. The method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to claim 1, characterized in that, The ratio of target production capacity to matrix production capacity is obtained based on the unobstructed flow rate of the pure matrix and the unobstructed flow rate after theoretical fracturing production increase, specifically as follows: Among them, FOI fac r is the ratio of target capacity to substrate capacity. e r is the gas reservoir outflow radius. w r is the radius of the wellbore. w "This is the equivalent wellbore radius after theoretical fracturing." 5. The method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to claim 1, characterized in that, The method for obtaining the equivalent wellbore radius for wellbore modification based on the ratio of natural productivity to matrix productivity is as follows: Where, r w1 ' is the equivalent wellbore radius due to natural fractures, n1 is the first equivalent fracturing stimulation number, x f Where is the productivity coefficient and P is the formation pressure.

6. The method for quantitatively characterizing the fracturing effect of high-pressure gas wells according to claim 1, characterized in that, The equivalent wellbore radius after fracturing is obtained based on the ratio of target production capacity to matrix production capacity. Specifically: Where, r w1 " is the equivalent wellbore radius after fracturing, n2 is the first equivalent fracturing stimulation number, x" f Where is the productivity coefficient and P is the formation pressure.

7. A method for quantitatively characterizing the fracturing effect of high-pressure gas wells, characterized in that, include: The first data acquisition module is used to acquire the unobstructed flow rate of pure matrix, the unobstructed flow rate before fracturing modification, and the unobstructed flow rate after theoretical fracturing production increase. The second data acquisition module is used to obtain the ratio of natural production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate before fracturing; and to obtain the ratio of target production capacity to matrix production capacity based on the unobstructed flow rate of pure matrix and the unobstructed flow rate after theoretical fracturing production increase. The first fracturing number acquisition module is used to obtain the equivalent wellbore radius of natural fractures on wellbore modification based on the ratio of natural production capacity to matrix production capacity, and to obtain the first equivalent fracturing number based on the equivalent wellbore radius of natural fractures on wellbore modification. The second fracturing number acquisition module is used to obtain the equivalent wellbore radius after fracturing based on the ratio of target production capacity to matrix production capacity, and to obtain the second equivalent fracturing number based on the equivalent wellbore radius after fracturing. The comparison module is used to compare the first equivalent fracturing stimulation number and the second equivalent fracturing stimulation number to achieve a quantitative characterization of the fracturing effect of the gas well.

8. A terminal device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method for quantitatively characterizing the fracturing effect of high-pressure gas wells as described in any one of claims 1 to 6.

9. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the steps of the method for quantitatively characterizing the fracturing effect of high-pressure gas wells as described in any one of claims 1 to 6.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by the processor, it implements the steps of the method for quantitatively characterizing the fracturing effect of high-pressure gas wells as described in any one of claims 1 to 6.

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