CN108593771A - Damage strength computational methods and damage strength computing device - Google Patents

Abstract

The damage strength calculation method and damage strength calculation device provided by the invention relate to the technical field of shale hydration damage evaluation. Among them, the damage intensity calculation method includes: obtaining the first acoustic time difference, the first attenuation coefficient, the first maximum amplitude, and the first main frequency of the shale; obtaining the second acoustic time difference, the second Attenuation coefficient, the second maximum amplitude and the second main frequency; according to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude, the first main frequency and The damage intensity after shale hydration is calculated by the second main frequency. Through the above method, the problem of low reliability of the damage strength of shale after hydration calculated in the prior art can be improved.

Description

Damage intensity calculation method and damage intensity calculation device

technical field

The invention relates to the technical field of shale hydration damage evaluation, in particular to a damage strength calculation method and a damage strength calculation device.

Background technique

The problem of wellbore instability has always been a major and difficult problem in the oil and gas industries. Among them, during the drilling process of hard and brittle shale formations, the drilling fluid will cause hydration damage to the shale and reduce the stability of the wellbore wall, resulting in frequent downhole complex situations and affecting safe drilling. The hydration damage evaluation of hard and brittle shale has been extensively studied in the field of drilling. Considering that the drilling operation is located in deep formations, usually based on petrophysical characteristics, well logging information is used to obtain formation rock information, and the impact of drilling fluid on water in shale formations is evaluated. chemical damage. Among the many logging information, acoustic logging is the most widely used. During the propagation of sound waves in rock mass media, they carry extremely rich acoustic information. Especially after hydration, changes in the internal structure of the rock will lead to changes in the acoustic properties of the rock, so the hydration damage can be quantitatively evaluated based on the acoustic properties of the rock.

The inventors have found that the current hydration evaluation method based on acoustic characteristics mainly uses acoustic transit time as the index, ignoring other acoustic characteristics of shale, so that it cannot fully and accurately reflect the hydration damage intensity of shale, resulting in the calculated shale water The problem of the low reliability of the damage strength after chemicalization.

Contents of the invention

In view of this, the object of the present invention is to provide a damage strength calculation method and a damage strength calculation device to improve the low reliability of the calculated damage strength of shale after hydration in the prior art.

In order to achieve the above purpose, the embodiment of the present invention adopts the following technical solutions:

A damage intensity calculation method for evaluating shale hydration damage, the method comprising:

Acquiring the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency of the shale, wherein the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency The frequency is generated based on ultrasonic transmission treatment of the shale;

Obtaining the second acoustic time difference, second attenuation coefficient, second maximum amplitude, and second main frequency of the shale, wherein the second acoustic time difference, second attenuation coefficient, second maximum amplitude, and second main frequency are based on Generated by ultrasonic transmission treatment of shale after hydration treatment;

According to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude, the first main frequency The first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient are respectively calculated according to the preset formula with the second main frequency;

The damage intensity after hydration of the shale is calculated according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient according to a preset formula.

In a preferred embodiment of the present invention, in the above damage intensity calculation method, the step of obtaining the first acoustic time difference includes:

Obtaining the initial first-wave take-off time, the shale first-wave take-off time, and the length of the shale respectively, wherein the initial first-wave take-off time is generated based on ultrasonic transmission processing after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, The take-off time of the first wave of the shale is generated based on ultrasonic transmission treatment after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction;

The first acoustic wave time difference is calculated according to the initial first wave take-off time, the first shale wave take-off time and the length of the shale according to a preset rule.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation method, the step of obtaining the first attenuation coefficient includes:

Obtain the initial first wave amplitude, the shale first wave amplitude and the length of the shale respectively, wherein the initial first wave amplitude is generated based on ultrasonic transmission processing after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, and the page The rockhead wave amplitude is generated based on ultrasonic transmission processing after the excitation probe and the reception probe are respectively arranged at both ends of the shale in the length direction;

The first attenuation coefficient is calculated according to a preset rule according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation method, the step of obtaining the first maximum amplitude and the first main frequency includes:

Acquiring an acoustic time-domain signal generated based on ultrasonic transmission processing of the shale, and obtaining the first maximum amplitude from the acoustic time-domain signal;

The acoustic time domain signal is subjected to Fourier transform processing to obtain an acoustic frequency domain signal, and the first main frequency is obtained from the acoustic frequency domain signal.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation method, the preset formulas for calculating the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient include:

Among them, S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively, and Δt(0) and Δt(s) are the first acoustic wave The time difference and the second acoustic time difference, At(0) and At(s) are the first attenuation coefficient and the second attenuation coefficient respectively, r(0) and r(s) are the first maximum amplitude and the second maximum amplitude respectively, fre (0) and fre(s) are the first main frequency and the second main frequency respectively.

In a preferred option of an embodiment of the present invention, in the above damage strength calculation method, the preset formula for calculating the damage strength of the shale after hydration includes:

Wherein, S is the damage intensity of the shale after hydration, and S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively.

An embodiment of the present invention also provides a damage intensity calculation device for evaluating shale hydration damage, and the device includes:

The first parameter acquisition module is used to acquire the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency of the shale, wherein the first acoustic time difference, first attenuation coefficient, The first maximum amplitude and the first main frequency are generated based on ultrasonic transmission treatment of the shale;

The second parameter acquisition module is used to acquire the second acoustic time difference, the second attenuation coefficient, the second maximum amplitude and the second main frequency of the shale, wherein the second acoustic time difference, the second attenuation coefficient, the second The maximum amplitude and the second main frequency are generated based on ultrasonic transmission treatment of shale after hydration treatment;

A damage coefficient calculation module, configured to calculate according to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude , the first main frequency and the second main frequency are respectively calculated according to a preset formula to obtain a first damage coefficient, a second damage coefficient, a third damage coefficient and a fourth damage coefficient;

The damage intensity calculation module is used to calculate and obtain the damage intensity of the shale after hydration according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient according to a preset formula.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation device, the first parameter acquisition module includes:

The time parameter acquisition sub-module is used to obtain the initial first-wave take-off time, the first-wave take-off time of the shale and the length of the shale respectively, wherein the initial first-wave take-off time is based on the excitation probe and the receiving probe of the ultrasonic transilluminator Ultrasonic transmission processing is performed after docking, and the first wave take-off time of the shale is generated based on ultrasonic transmission processing after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction;

The sonic time difference calculation sub-module is used to calculate and obtain the first sonic time difference according to the initial first wave take-off time, the shale first wave take-off time and the length of the shale according to preset rules.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation device, the first parameter acquisition module further includes:

The amplitude parameter acquisition sub-module is used to obtain the initial first wave amplitude, the shale first wave amplitude and the length of the shale respectively, wherein the initial first wave amplitude is based on the docking of the excitation probe and the receiving probe of the ultrasonic transilluminator. Generated by ultrasonic transmission processing, the first wave amplitude of the shale is generated based on ultrasonic transmission processing after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction;

The attenuation coefficient calculation sub-module is used to calculate and obtain the first attenuation coefficient according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale according to preset rules.

In a preferred option of the embodiment of the present invention, in the above damage intensity calculation device, the first parameter acquisition module further includes:

The amplitude parameter acquisition sub-module is used to acquire the acoustic wave time-domain signal generated based on the ultrasonic transmission processing of the shale, and obtain the first maximum amplitude from the acoustic wave time-domain signal;

The main frequency parameter acquisition sub-module is configured to perform Fourier transform processing on the sound wave time domain signal to obtain the sound wave frequency domain signal, and obtain the first main frequency from the sound wave frequency domain signal.

The damage intensity calculation method and damage intensity calculation device provided by the present invention respectively obtain the acoustic time difference, attenuation coefficient, maximum amplitude and main frequency of the shale to be evaluated before and after hydration treatment, and based on the damage intensity of each parameter to the shale Calculations are performed to comprehensively evaluate the hydration damage of shale, thereby improving the problem of low reliability of the damage strength of shale after hydration calculated in the prior art.

In order to make the above-mentioned objects, features and advantages of the present invention more comprehensible, preferred embodiments will be described in detail below together with the accompanying drawings.

Description of drawings

FIG. 1 is a structural block diagram of an electronic device provided by an embodiment of the present invention.

Fig. 2 is a schematic flowchart of a damage intensity calculation method provided by an embodiment of the present invention.

FIG. 3 is a schematic flowchart of step S110 in FIG. 2 .

FIG. 4 is another schematic flowchart of step S110 in FIG. 2 .

FIG. 5 is another schematic flowchart of step S110 in FIG. 2 .

Fig. 6 is a structural block diagram of a damage intensity calculation device provided by an embodiment of the present invention.

Fig. 7 is a structural block diagram of a first parameter acquisition module provided by an embodiment of the present invention.

Fig. 8 is another structural block diagram of the first parameter acquisition module provided by the embodiment of the present invention.

Fig. 9 is another structural block diagram of the first parameter acquisition module provided by the embodiment of the present invention.

Icons: 10-electronic equipment; 12-memory; 14-processor; 100-damage strength calculation device; 110-first parameter acquisition module; 111-time parameter acquisition submodule; 112-acoustic time difference calculation submodule; 113-amplitude Parameter acquisition sub-module; 114-attenuation coefficient calculation sub-module; 115-amplitude parameter acquisition sub-module; 116-main frequency parameter acquisition sub-module; 130-second parameter acquisition module; 150-damage coefficient calculation module; 170-damage strength calculation module.

Detailed ways

In order to make the purpose, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments It is only a part of embodiments of the present invention, but not all embodiments. The components of the embodiments of the invention generally described and illustrated in the figures herein may be arranged and designed in a variety of different configurations.

Accordingly, 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 represents selected embodiments of the invention. Based on the embodiments of the present invention, all other embodiments obtained by persons of ordinary skill in the art without creative efforts fall within the protection scope of the present invention.

It should be noted that like numerals and letters denote similar items in the following figures, therefore, once an item is defined in one figure, it does not require further definition and explanation in subsequent figures. In the description of the present invention, the terms "first", "second", "third", "fourth" and so on are only used for distinguishing descriptions, and should not be interpreted as merely or implying relative importance.

As shown in FIG. 1 , an embodiment of the present invention provides an electronic device 10 that can be used to evaluate hydration damage of shale. Wherein, the electronic device 10 may include a memory 12 , a processor 14 and a damage intensity calculation device 100 .

The memory 12 and the processor 14 are electrically connected directly or indirectly to realize data transmission or interaction. For example, these components can be electrically connected to each other through one or more communication buses or signal lines. The damage intensity calculation device 100 includes at least one software function module that can be stored in the memory 12 in the form of software or firmware. The processor 14 is used to execute executable computer programs stored in the memory 12 , for example, software function modules and computer programs included in the damage intensity calculation device 100 , so as to realize the damage intensity calculation method.

Wherein, the memory 12 can be, but not limited to, random access memory (Random Access Memory, RAM), read-only memory (Read Only Memory, ROM), programmable read-only memory (Programmable Read-OnlyMemory, PROM), Erasable Programmable Read-Only Memory (EPROM), Electric Erasable Programmable Read-Only Memory (EEPROM), etc. Wherein, the memory 12 is used to store programs, and the processor 14 executes the programs after receiving execution instructions.

The processor 14 may be an integrated circuit chip with signal processing capabilities. Above-mentioned processor 14 can be general-purpose processor, comprises central processing unit (Central Processing Unit, CPU), network processor (Network Processor, NP) etc.; Can also be digital signal processor (DSP), application-specific integrated circuit (ASIC) ), field programmable gate array (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components. Various methods, steps and logic block diagrams disclosed in the embodiments of the present invention may be implemented or executed. A general-purpose processor may be a microprocessor, or the processor may be any conventional processor, or the like.

It can be understood that the structure shown in FIG. 1 is only for illustration, and the electronic device 10 may also include more or less components than those shown in FIG. 1 , or have a configuration different from that shown in FIG. 1 . Each component shown in Fig. 1 may be implemented by hardware, software or a combination thereof.

Optionally, the specific type of the electronic device 10 is not limited, for example, it may be, but not limited to, a smart phone, a personal computer (personal computer, PC), a tablet computer, a personal digital assistant (personal digital assistant, PDA), Mobile Internet device (mobile Internet device, MID), web (website) server, data server, computer, mobile Internet device (mobile Internet device, MID) and other devices with processing functions.

With reference to FIG. 2 , an embodiment of the present invention also provides a damage intensity calculation method applicable to the above-mentioned electronic device 10 . Wherein, the method steps defined by the process related to the method may be implemented by the processor 14 . The specific process shown in FIG. 2 will be described in detail below.

Step S110, acquiring the first acoustic time difference, the first attenuation coefficient, the first maximum amplitude and the first main frequency of the shale.

In this embodiment, the first acoustic time difference, the first attenuation coefficient, the first maximum amplitude, and the first main frequency are generated based on ultrasonic transmission treatment of the shale.

Wherein, before performing ultrasonic transmission treatment on the shale, in order to ensure the validity and reliability of the obtained parameters, the extracted shale can be processed, for example, an air drill can be used for drilling to obtain the shale The core of the rock, and the two ends of the core are cut so that the two end faces are perpendicular to the axis of the core.

Step S130, acquiring the second acoustic time difference, the second attenuation coefficient, the second maximum amplitude and the second main frequency of the shale.

In this embodiment, the second acoustic time difference, the second attenuation coefficient, the second maximum amplitude, and the second main frequency are generated based on ultrasonic transmission treatment of shale after hydration treatment.

Wherein, the manner of hydrating the shale is not limited, for example, it may be performed by any liquid (for example, water), or may be performed by drilling fluid. In this embodiment, in order to ensure that the hydration treatment can more truly reflect the hydration effect in practical applications, drilling fluid can be used.

Step S150, according to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude, the first The first main frequency and the second main frequency are respectively calculated according to preset formulas to obtain a first damage coefficient, a second damage coefficient, a third damage coefficient and a fourth damage coefficient.

Wherein, the preset formulas for calculating the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient are not limited, and can be set according to actual application requirements. For example, for the acoustic time difference, the first damage coefficient can be directly The difference between the acoustic time difference and the second acoustic time difference is used as the first damage coefficient. In this embodiment, in order to ensure high consistency when performing step S170 through various coefficients, the preset formula may include:

Among them, S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively, and Δt(0) and Δt(s) are the first acoustic wave The time difference and the second acoustic time difference, At(0) and At(s) are the first attenuation coefficient and the second attenuation coefficient respectively, r(0) and r(s) are the first maximum amplitude and the second maximum amplitude respectively, fre (0) and fre(s) are the first main frequency and the second main frequency respectively.

Step S170, calculating according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient according to a preset formula to obtain the damage intensity of the shale after hydration.

Wherein, the preset formula for calculating the damage intensity is not limited, and can be set according to actual application requirements, for example, it can be the median value of the four coefficients, or the average value of the four coefficients, or other Calculation. In this embodiment, the preset formula for calculating the damage intensity may include:

Wherein, S is the damage intensity of the shale after hydration, and S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively.

Further, in this embodiment, the method of obtaining the first acoustic time difference, the first attenuation coefficient, the first maximum amplitude, and the first main frequency through step S110 is not limited, and can be set according to actual application requirements. 3. Step S110 may include steps S111 and S112 to obtain the first acoustic time difference.

Step S111 , acquiring the initial first-wave take-off time, the shale first-wave take-off time, and the length of the shale respectively.

In this embodiment, the initial first-wave take-off time is generated based on the ultrasonic transmission process after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, and the shale first-wave take-off time is based on separately connecting the excitation probe and the receiving probe It is installed at both ends of the shale in the longitudinal direction and then generated by ultrasonic transmission treatment.

Step S112 , according to the initial first-wave take-off time, the first-wave take-off time of the shale, and the length of the shale, calculate the first acoustic time difference according to preset rules.

In this embodiment, the preset rule for calculating the first acoustic time difference may be:

Among them, Δt is the time difference of the first acoustic wave, _t1 is the take-off time of the initial first wave, _t2 is the take-off time of the first wave of the shale, and L is the length of the shale.

Referring to FIG. 4 , in this embodiment, step S110 may further include step S113 and step S114 to obtain the first attenuation coefficient.

Step S113, obtaining the initial first-wave amplitude, the first-wave amplitude of the shale, and the length of the shale respectively.

In this embodiment, the initial first wave amplitude is generated based on ultrasonic transmission processing after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, and the shale first wave amplitude is based on setting the excitation probe and the receiving probe respectively at The two ends of the shale in the length direction are then formed by ultrasonic transmission treatment.

Step S114 , according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale, calculate the first attenuation coefficient according to a preset rule.

In this embodiment, the preset rule for calculating the first attenuation coefficient may be:

Among them, At is the first attenuation coefficient, A ₀ is the amplitude of initial first wave, A is the amplitude of first wave of shale, and L is the length of shale.

Referring to FIG. 5 , in this embodiment, step S110 may further include step S115 and step S116 to obtain the first maximum amplitude and the first main frequency.

Step S115, acquiring an acoustic time-domain signal generated based on ultrasonic transmission processing of the shale, and obtaining a first maximum amplitude from the acoustic time-domain signal.

Step S116, performing Fourier transform processing on the acoustic wave time domain signal to obtain an acoustic wave frequency domain signal, and obtain a first main frequency from the acoustic wave frequency domain signal.

In this embodiment, the fluctuating time-domain signal can be expanded in order of frequency through Fourier transform to obtain the acoustic frequency-domain signal, and the first main frequency can be obtained from the acoustic frequency-domain signal. Among them, the principle of Fourier transform can be:

Among them, f is the frequency, x(t) is the time domain function, X(f) is the complex function of the frequency domain of the sound wave, and t is a time point in the sound wave propagation.

Wherein, the method of obtaining the second acoustic wave time difference, the second attenuation coefficient, the second maximum amplitude, and the second main frequency in step S130 is not limited, and can be set according to actual application requirements, for example, it can be the same as that of step S110 The manner is the same, or may be different from that of step S110. In this embodiment, in order to ensure that the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum The damage coefficients calculated by the amplitude, the first main frequency, and the second main frequency have high reliability, and the acquisition method of the parameters in step S130 is the same as that in step S110. Specifically, please combine the above for Explanation of each step included in step S110.

Furthermore, in order to ensure the evaluation of shale hydration damage has high reliability, in this embodiment, the damage intensity can be calculated separately based on different hydration times of the same shale to obtain A corresponding relationship between the damage intensity of the shale and the hydration time.

Moreover, in this embodiment, the evaluation of hydration damage can also be performed on different shales, so that a more reliable evaluation can be obtained by comparing the damage intensities of different shales.

With reference to FIG. 6 , an embodiment of the present invention also provides a damage intensity calculation device 100 applicable to the above-mentioned electronic device 10 . Wherein, the damage intensity calculation device 100 may include a first parameter acquisition module 110 , a second parameter acquisition module 130 , a damage coefficient calculation module 150 and a damage intensity calculation module 170 .

The first parameter acquisition module 110 is configured to acquire the first acoustic time difference, the first attenuation coefficient, the first maximum amplitude and the first main frequency of the shale, wherein the first acoustic time difference, the first The attenuation coefficient, the first maximum amplitude and the first main frequency are generated based on ultrasonic transmission treatment of the shale. In this embodiment, the first parameter acquisition module 110 may be configured to execute step S110 shown in FIG. 2 , and for a specific description of the first parameter acquisition module 110 , reference may be made to the foregoing description of step S110 .

The second parameter acquisition module 130 is configured to acquire the second acoustic time difference, second attenuation coefficient, second maximum amplitude and second main frequency of the shale, wherein the second acoustic time difference, second attenuation coefficient , the second maximum amplitude and the second main frequency are generated based on ultrasonic transmission treatment of shale after hydration treatment. In this embodiment, the second parameter acquisition module 130 may be configured to execute step S130 shown in FIG. 2 , and for a specific description of the second parameter acquisition module 130 , reference may be made to the foregoing description of step S130 .

The damage coefficient calculation module 150 is configured to calculate according to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second The second maximum amplitude, the first main frequency and the second main frequency are respectively calculated according to a preset formula to obtain a first damage coefficient, a second damage coefficient, a third damage coefficient and a fourth damage coefficient. In this embodiment, the damage coefficient calculation module 150 may be configured to execute step S150 shown in FIG. 2 , and for a specific description of the damage coefficient calculation module 150 , reference may be made to the foregoing description of step S150 .

The damage intensity calculation module 170 is configured to calculate the damage intensity of the shale after hydration according to a preset formula according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient. In this embodiment, the damage intensity calculation module 170 can be used to execute step S170 shown in FIG. 2 , and for a specific description of the damage intensity calculation module 170 , reference can be made to the previous description of step S170 .

Referring to FIG. 7 , in this embodiment, the first parameter acquisition module 110 may include a time parameter acquisition submodule 111 and a sound wave time difference calculation submodule 112 .

The time parameter acquisition sub-module 111 is used to acquire the initial first-wave take-off time, the first-wave take-off time of shale and the length of the shale respectively, wherein the initial first-wave take-off time is based on the excitation probe of the ultrasonic transilluminator It is generated by ultrasonic transmission after docking with the receiving probe, and the first wave take-off time of the shale is generated based on the ultrasonic transmission process after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction. In this embodiment, the time parameter acquisition sub-module 111 can be used to execute step S111 shown in FIG. 3 , and for a specific description of the time parameter acquisition sub-module 111 , refer to the previous description of step S111 .

The acoustic time difference calculation sub-module 112 is configured to calculate and obtain the first acoustic time difference according to the initial first-wave take-off time, the first-wave take-off time of the shale, and the length of the shale according to preset rules. In this embodiment, the acoustic time difference calculation sub-module 112 can be used to execute step S112 shown in FIG. 3 , and for a specific description of the acoustic time difference calculation sub-module 112 , reference can be made to the previous description of step S112 .

Referring to FIG. 8 , in this embodiment, the first parameter acquisition module 110 may further include an amplitude parameter acquisition submodule 113 and an attenuation coefficient calculation submodule 114 .

The amplitude parameter acquisition sub-module 113 is used to respectively acquire the initial first wave amplitude, the shale first wave amplitude and the length of the shale, wherein the initial first wave amplitude is based on the excitation probe and the receiving probe of the ultrasonic transilluminator After docking, it is generated by ultrasonic transmission treatment, and the amplitude of the first wave of the shale is generated based on the ultrasonic transmission treatment after the excitation probe and the receiving probe are respectively arranged at the two ends of the shale in the length direction. In this embodiment, the amplitude parameter acquisition sub-module 113 can be used to execute step S113 shown in FIG. 4 , and for a specific description of the amplitude parameter acquisition sub-module 113 , reference can be made to the previous description of step S113 .

The attenuation coefficient calculation sub-module 114 is configured to calculate and obtain the first attenuation coefficient according to a preset rule according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale. In this embodiment, the attenuation coefficient calculation sub-module 114 may be configured to execute step S114 shown in FIG. 4 , and for a specific description of the attenuation coefficient calculation sub-module 114 , reference may be made to the foregoing description of step S114 .

Referring to FIG. 9 , in this embodiment, the first parameter acquisition module 110 may further include an amplitude parameter acquisition submodule 115 and a main frequency parameter acquisition submodule 116 .

The amplitude parameter acquisition sub-module 115 is configured to acquire an acoustic time-domain signal generated based on ultrasonic transmission processing of the shale, and obtain the first maximum amplitude from the acoustic time-domain signal. In this embodiment, the amplitude parameter acquisition sub-module 115 can be used to execute step S115 shown in FIG. 5 , and for a specific description of the amplitude parameter acquisition sub-module 115 , reference can be made to the previous description of step S115 .

The main frequency parameter acquisition sub-module 116 is configured to perform Fourier transform processing on the sound wave time domain signal to obtain a sound wave frequency domain signal, and obtain a first main frequency from the sound wave frequency domain signal. In this embodiment, the main frequency parameter acquisition sub-module 116 can be used to execute step S116 shown in FIG. 5 , and for the specific description of the main frequency parameter acquisition sub-module 116 , refer to the previous description of step S116 .

In summary, the damage intensity calculation method and the damage intensity calculation device 100 provided by the present invention obtain the acoustic time difference, attenuation coefficient, maximum amplitude, and dominant frequency of the shale to be evaluated before and after hydration treatment, and based on each parameter The damage strength of the shale is calculated to evaluate the hydration damage of the shale more comprehensively, thereby improving the problem of low reliability of the damage strength of the shale after hydration calculated in the prior art.

In the several embodiments provided by the embodiments of the present invention, it should be understood that the disclosed devices and methods may also be implemented in other ways. The device and method embodiments described above are only illustrative. For example, the flowcharts and block diagrams in the accompanying drawings show possible implementation architectures of devices, methods and computer program products according to multiple embodiments of the present invention, function and operation. In this regard, each block in a flowchart or block diagram may represent a module, program segment, or part of code that includes one or more Executable instructions. It should also be noted that, in some alternative implementations, the functions noted in the block may occur out of the order noted in the figures. For example, two blocks in succession may, in fact, be executed substantially concurrently, or they may sometimes be executed in the reverse order, depending upon the functionality involved. It should also be noted that each block of the block diagrams and/or flowchart illustrations, and combinations of blocks in the block diagrams and/or flowchart illustrations, can be implemented by a dedicated hardware-based system that performs the specified function or action , or may be implemented by a combination of dedicated hardware and computer instructions.

In addition, each functional module in each embodiment of the present invention can be integrated together to form an independent part, or each module can exist independently, or two or more modules can be integrated to form an independent part.

If the functions are realized in the form of software function modules and sold or used as independent products, they can be stored in a computer-readable storage medium. Based on this understanding, the essence of the technical solution of the present invention or the part that contributes to the prior art or the part of the technical solution can be embodied in the form of a software product, and the computer software product is stored in a storage medium, including Several instructions are used to make a computer device (which may be a personal computer, an electronic device, or a network device, etc.) execute all or part of the steps of the method described in each embodiment of the present invention. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), magnetic disk or optical disk and other media that can store program codes. . It should be noted that, in this document, the terms "comprising", "comprising" or any other variation thereof are intended to cover a non-exclusive inclusion such that a process, method, article or apparatus comprising a set of elements includes not only those elements, It also includes other elements not expressly listed, or elements inherent in the process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising a ..." does not exclude the presence of additional identical elements in the process, method, article or apparatus comprising said element.

The above descriptions are only preferred embodiments of the present invention, and are not intended to limit the present invention. For those skilled in the art, the present invention may have various modifications and changes. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included within the protection scope of the present invention.

Claims (10)

1. A damage intensity calculation method, used to evaluate the hydration damage of shale, is characterized in that, said method comprises: Acquiring the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency of the shale, wherein the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency The frequency is generated based on ultrasonic transmission treatment of the shale; Obtaining the second acoustic time difference, second attenuation coefficient, second maximum amplitude, and second main frequency of the shale, wherein the second acoustic time difference, second attenuation coefficient, second maximum amplitude, and second main frequency are based on Generated by ultrasonic transmission treatment of shale after hydration treatment; According to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude, the first main frequency The first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient are respectively calculated according to the preset formula with the second main frequency; The damage intensity after hydration of the shale is calculated according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient according to a preset formula. 2. The damage intensity calculation method according to claim 1, wherein the step of obtaining the first acoustic time difference comprises: Obtaining the initial first-wave take-off time, the shale first-wave take-off time, and the length of the shale respectively, wherein the initial first-wave take-off time is generated based on ultrasonic transmission processing after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, The take-off time of the first wave of the shale is generated based on ultrasonic transmission treatment after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction; The first acoustic wave time difference is calculated according to the initial first wave take-off time, the first shale wave take-off time and the length of the shale according to a preset rule. 3. The damage intensity calculation method according to claim 1, wherein the step of obtaining the first attenuation coefficient comprises: Obtain the initial first wave amplitude, the shale first wave amplitude and the length of the shale respectively, wherein the initial first wave amplitude is generated based on ultrasonic transmission processing after docking the excitation probe and the receiving probe of the ultrasonic transilluminator, and the page The rockhead wave amplitude is generated based on ultrasonic transmission processing after the excitation probe and the reception probe are respectively arranged at both ends of the shale in the length direction; The first attenuation coefficient is calculated according to a preset rule according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale. 4. The damage intensity calculation method according to claim 1, wherein the step of obtaining the first maximum amplitude and the first main frequency comprises: Acquiring an acoustic time-domain signal generated based on ultrasonic transmission processing of the shale, and obtaining the first maximum amplitude from the acoustic time-domain signal; The acoustic time domain signal is subjected to Fourier transform processing to obtain an acoustic frequency domain signal, and the first main frequency is obtained from the acoustic frequency domain signal. 5. The damage intensity calculation method according to any one of claims 1-4, wherein the preset formulas for calculating the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient include : Among them, S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively, and Δt(0) and Δt(s) are the first acoustic wave The time difference and the second acoustic time difference, At(0) and At(s) are the first attenuation coefficient and the second attenuation coefficient respectively, r(0) and r(s) are the first maximum amplitude and the second maximum amplitude respectively, fre (0) and fre(s) are the first main frequency and the second main frequency respectively. 6. The damage intensity calculation method according to any one of claims 1-4, wherein the preset formula for calculating the damage intensity after hydration of the shale comprises: Wherein, S is the damage intensity of the shale after hydration, and S _t , S _a , S _r , and S _f are the first damage coefficient, the second damage coefficient, the third damage coefficient, and the fourth damage coefficient, respectively. 7. A damage intensity calculation device for evaluating the hydration damage of shale, characterized in that the device comprises: The first parameter acquisition module is used to acquire the first acoustic time difference, first attenuation coefficient, first maximum amplitude and first main frequency of the shale, wherein the first acoustic time difference, first attenuation coefficient, The first maximum amplitude and the first main frequency are generated based on ultrasonic transmission treatment of the shale; The second parameter acquisition module is used to acquire the second acoustic time difference, the second attenuation coefficient, the second maximum amplitude and the second main frequency of the shale, wherein the second acoustic time difference, the second attenuation coefficient, the second The maximum amplitude and the second main frequency are generated based on ultrasonic transmission treatment of shale after hydration treatment; A damage coefficient calculation module, configured to calculate according to the first acoustic time difference and the second acoustic time difference, the first attenuation coefficient and the second attenuation coefficient, the first maximum amplitude and the second maximum amplitude , the first main frequency and the second main frequency are respectively calculated according to a preset formula to obtain a first damage coefficient, a second damage coefficient, a third damage coefficient and a fourth damage coefficient; The damage intensity calculation module is used to calculate and obtain the damage intensity of the shale after hydration according to the first damage coefficient, the second damage coefficient, the third damage coefficient and the fourth damage coefficient according to a preset formula. 8. The damage intensity calculation device according to claim 7, wherein the first parameter acquisition module comprises: The time parameter acquisition sub-module is used to obtain the initial first-wave take-off time, the first-wave take-off time of the shale and the length of the shale respectively, wherein the initial first-wave take-off time is based on the excitation probe and the receiving probe of the ultrasonic transilluminator Ultrasonic transmission processing is performed after docking, and the first wave take-off time of the shale is generated based on ultrasonic transmission processing after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction; The sonic time difference calculation sub-module is used to calculate and obtain the first sonic time difference according to the initial first wave take-off time, the shale first wave take-off time and the length of the shale according to preset rules. 9. The damage intensity calculation device according to claim 7, wherein the first parameter acquisition module further comprises: The amplitude parameter acquisition sub-module is used to obtain the initial first wave amplitude, the shale first wave amplitude and the length of the shale respectively, wherein the initial first wave amplitude is based on the docking of the excitation probe and the receiving probe of the ultrasonic transilluminator. Generated by ultrasonic transmission processing, the first wave amplitude of the shale is generated based on ultrasonic transmission processing after the excitation probe and the receiving probe are respectively arranged at both ends of the shale in the length direction; The attenuation coefficient calculation sub-module is used to calculate and obtain the first attenuation coefficient according to the initial first wave amplitude, the shale first wave amplitude and the length of the shale according to preset rules. 10. The damage intensity calculation device according to claim 7, wherein the first parameter acquisition module further comprises: The amplitude parameter acquisition sub-module is used to acquire the acoustic wave time-domain signal generated based on the ultrasonic transmission processing of the shale, and obtain the first maximum amplitude from the acoustic wave time-domain signal; The main frequency parameter acquisition sub-module is configured to perform Fourier transform processing on the sound wave time domain signal to obtain the sound wave frequency domain signal, and obtain the first main frequency from the sound wave frequency domain signal.