Reservoir transformation volume calculation method, system and device and storage medium

Abstract

The invention belongs to the technical field of oil-gas exploration, and particularly relates to a reservoir transformation volume calculation method, system and device and a storage medium. The method comprises the steps that the distribution condition of natural fractures around a shaft is obtained; arranging the microseism event points in the fracturing time period to obtain the distribution condition of cracks around the shaft represented by the microseism event points; screening out microseism event points corresponding to natural fractures in the fractures around the shaft on the basis of the distribution condition of the natural fractures around the shaft; classifying the screened micro-seismic event points and screening out effective micro-seismic event points; and calculating the reservoir transformation volume according to the effective microseismic event points. According to the method, the relative relation between the microseismic event points and the reservoir transformation volume is clarified by explaining the microseismic generation mechanism, so that effective microseismic event points are screened out through event point classification, the reservoir transformation volume is calculated, and fracturing effect evaluation, development scheme deployment and the like are effectively supported.

Description

Technical Field

[0001] The present invention belongs to the technical field of oil and gas exploration, and in particular relates to a reservoir transformation volume calculation method, system, device and storage medium. Background Art

[0002] With the large-scale development of unconventional oil and gas reservoirs, microseismic monitoring technology has developed rapidly as a key technology for real-time monitoring of hydraulic fracturing processes and evaluating the effects of reservoir reconstruction after fracturing. During hydraulic fracturing, fluid is injected into dense low-permeability reservoirs under high pressure, causing natural fractures to expand continuously and brittle rocks to shear and slip, forming an interlaced fracture network, thereby increasing the reconstruction volume. At the same time, shear and slip will radiate elastic seismic wave energy outward. Microseismic monitoring technology locates microseismic event points by monitoring and collecting seismic wave signals, and uses the distribution characteristics of fracture event points to analyze the distribution of artificial fractures and rock properties and evaluate the effects of fracturing reconstruction.

[0003] The main purpose of hydraulic fracturing is to form a three-dimensional fracture network system, increase the seepage capacity, and greatly transform the effective oil leakage volume of the reservoir, thereby improving the reservoir utilization rate and ultimate recovery rate. Estimating the scale of its transformation is an important means to evaluate the effect of hydraulic fracturing and deploy development plans. In hydraulic fracturing construction, the expansion and extension scale of the fracture network in the reservoir can be quantitatively evaluated and calculated by the stimulated reservoir volume (SRV). Numerical simulation analysis and engineering practice have found that SRV and the cumulative production of oil wells after fracturing show a significant positive correlation, indicating that the larger the SRV, the higher the fracture complexity, the better the effect of reservoir transformation, and the higher the production of oil and gas wells. Summary of the invention

[0004] In view of the above problems, the present invention provides a method for calculating reservoir transformation volume, the method comprising:

[0005] Obtain the distribution of natural fractures around the wellbore;

[0006] The microseismic event points within the fracturing period are sorted out to obtain the distribution of cracks around the wellbore represented by the microseismic event points;

[0007] Based on the distribution of natural fractures around the wellbore, the microseismic event points corresponding to the natural fractures in the fractures around the wellbore are screened out;

[0008] Classifying the screened microseismic event points and screening out effective microseismic event points, wherein the effective microseismic event points are microseismic event points generated by natural fractures that form fluid seepage channels with the wellbore;

[0009] The reservoir transformation volume is calculated based on the effective microseismic event points.

[0010] Preferably, the distribution conditions include fracture density, direction and inclination.

[0011] Preferably, the microseismic event points within the fracturing time period are sorted out, including:

[0012] Arrange the microseismic event points into a digital sequence that occurs sequentially;

[0013] Connect the microseismic event points at the same time into a line, and the position of the line is the location where the cracks around the wellbore exist.

[0014] Preferably, the fractures around the wellbore include hydraulic fractures and natural fractures.

[0015] Preferably, based on the distribution of natural fractures around the wellbore, microseismic event points corresponding to natural fractures in the fractures around the wellbore are screened out, including:

[0016] According to the distribution of the natural fractures around the wellbore, the natural fractures in the fractures around the wellbore are screened out;

[0017] The corresponding microseismic event points are selected according to the natural fractures in the fractures around the wellbore.

[0018] Preferably, the screened microseismic event points are classified, including: based on the fracturing construction curve, the screened microseismic event points are classified according to the initial stage of fracturing, the middle stage of fracturing and the stage after fracturing.

[0019] Preferably, the fracturing construction curve includes a pumping pressure curve, a construction displacement curve and a sand concentration curve.

[0020] Preferably, the microseismic event point initially formed by the fracturing is an invalid microseismic event point;

[0021] The microseismic event points formed during the fracturing are effective microseismic event points;

[0022] The microseismic event point formed after the fracturing needs to be judged as a valid microseismic event point according to the location of the microseismic event point.

[0023] Preferably, the method for determining the microseismic event point formed after the fracturing is:

[0024] If the position of the microseismic event point formed after fracturing is connected with the position of the microseismic event point formed during fracturing, it is a valid microseismic event point; otherwise, it is an invalid microseismic event point.

[0025] Preferably, the calculation method of the reservoir transformation volume is an octree algorithm of a non-uniform grid.

[0026] The present invention also provides a reservoir transformation volume calculation system, the system comprising:

[0027] An acquisition module, used to obtain the distribution of natural fractures around the wellbore;

[0028] A sorting module is used to sort the microseismic event points within the fracturing time period to obtain the distribution of cracks around the wellbore represented by the microseismic event points;

[0029] The first screening module is used to screen out microseismic event points corresponding to natural fractures in the fractures around the wellbore based on the distribution of natural fractures around the wellbore;

[0030] The second screening module is used to classify the screened microseismic event points and screen out effective microseismic event points;

[0031] The calculation module is used to calculate the reservoir transformation volume according to the effective microseismic event points.

[0032] Preferably, the sorting module is used to sort the microseismic event points within the fracturing time period, including:

[0033] Arrange the microseismic event points into a digital sequence that occurs sequentially;

[0034] Connect the microseismic event points at the same time into a line, and the position of the line is the location where the cracks around the wellbore exist.

[0035] Preferably, the first screening module is used to screen out microseismic event points corresponding to natural fractures in the fractures around the wellbore based on the distribution of natural fractures around the wellbore, including:

[0036] According to the distribution of the natural fractures around the wellbore, the natural fractures in the fractures around the wellbore are screened out;

[0037] The corresponding microseismic event points are selected according to the natural fractures in the fractures around the wellbore.

[0038] Preferably, the second screening module is used to classify the screened microseismic event points, including:

[0039] Based on the fracturing construction curve, the selected microseismic event points are classified according to the beginning, middle and end of fracturing.

[0040] The present invention also provides a device for calculating reservoir transformation volume, the device comprising: a processor, a communication interface, a memory and a communication bus, wherein the processor, the communication interface and the memory communicate with each other via the communication bus;

[0041] Memory; and storage of computer programs;

[0042] A processor is configured to execute the reservoir transformation volume calculation method.

[0043] The present invention also provides a machine-readable storage medium, wherein instructions are stored on the machine-readable storage medium.

[0044] When the instruction is executed by a processor, the processor is configured to execute the reservoir stimulation volume calculation method.

[0045] The present invention has the following beneficial effects:

[0046] The present invention obtains the distribution of natural cracks around the wellbore, sorts out the microseismic event points within the fracturing time period, obtains the distribution of cracks around the wellbore represented by the microseismic event points, and based on the distribution of natural cracks around the wellbore, screens out the microseismic event points corresponding to the natural cracks in the cracks around the wellbore, classifies the screened microseismic event points and screens out the effective microseismic event points, and calculates the reservoir transformation volume according to the effective microseismic event points, which can make the calculation of the reservoir transformation volume more accurate. The present invention clarifies the relative relationship between microseismic event points and reservoir transformation volume by explaining the mechanism of microseismic generation, thereby screening out effective microseismic event points through event point classification, calculating the reservoir transformation volume, and effectively supporting the evaluation of fracturing effects and the deployment of development plans.

[0047] Other features and advantages of the present invention will be described in the following description, and partly become obvious from the description, or be understood by implementing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures pointed out in the description and the drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0049] Figure 1 A diagram showing a reservoir transformation volume calculation method according to an embodiment of the present invention;

[0050] Figure 2a and Figure 2b The FMI natural fracture interpretation result diagram of a well in an embodiment of the present invention is shown;

[0051] Figure 3 The interpretation result diagram of the 18th magnitude microseismic event point of a certain well in the embodiment of the present invention is shown;

[0052] Figure 4 The 18th-stage fracturing curve diagram of a well in an embodiment of the present invention is shown;

[0053] Figure 5a A microseismic event point diagram of all fracturing levels of a certain well in an embodiment of the present invention is shown;

[0054] Figure 5b A schematic diagram of calculating the reservoir transformation volume of a certain well in an embodiment of the present invention is shown;

[0055] Figure 6 A comparison chart of the SRV of a well and the production capacity of different production systems in an embodiment of the present invention is shown;

[0056] Figure 7 A diagram of a reservoir transformation volume calculation system in an embodiment of the present invention is shown;

[0057] Figure 8 A diagram of a reservoir transformation volume calculation device in an embodiment of the present invention is shown. DETAILED DESCRIPTION

[0058] In order to make the purpose, technical solution and advantages of the embodiments of the present invention clearer, the technical solution 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 are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0059] Generally, the reservoir transformation volume is calculated using microseismic event points by using all microseismic event points through an algorithm, without considering the generation mechanism of microseismic event points and the relative relationship between microseismic event points and reservoir transformation volume.

[0060] like Figure 1 As shown, the present invention proposes a method for calculating reservoir transformation volume, which comprises the following steps:

[0061] (1) Obtain the distribution of natural fractures around the wellbore;

[0062] The natural fracture orientation around the wellbore is obtained by using the fracture interpretation results of the well logging FMI (Formation MicroScanner Image). The specific method is as follows:

[0063] Microseismic events are mainly the response of hydraulic fracture expansion and shear slip of natural fractures. Microseismic events generated by hydraulic fractures belong to the scope of reservoir transformation, but not all microseismic events generated by natural fractures belong to the scope of reservoir transformation. During the fracturing process, the natural fractures around the wellbore are captured by hydraulic fractures to produce microseismic responses. The microseismic event points generated by these natural fractures belong to the scope of reservoir transformation. There are also some natural fractures that also produce microseismic responses due to stress disturbance, but these natural fractures are not captured by hydraulic fractures. The microseismic events generated by these natural fractures do not belong to the scope of reservoir transformation. When calculating the volume of reservoir transformation, the microseismic events generated by these natural fractures need to be excluded. Therefore, it is necessary to first determine the distribution of natural fractures around the wellbore. Formation microresistivity scanning imaging FMI can provide the development of natural fractures around the wellbore, including fracture density, strike, and inclination. First, the distribution of natural fractures around the wellbore is obtained through the FMI fracture interpretation results. As shown in Figure 2, the natural fractures of a well are relatively developed, and the overall direction is northwest-southeast.

[0064] (2) sorting out the microseismic event points during the fracturing period to obtain the distribution of cracks around the wellbore represented by the microseismic event points;

[0065] like Figure 3 As shown in the figure, when fracturing starts in a certain section, the number of microseismic event points before fracturing is zero, and the time when the microseismic event point first appears after fracturing starts is marked as 1. The number of microseismic event points appearing at this time may be one or more. There is hydraulic fracture expansion or fracture shear slip at the location of each microseismic event point. These microseismic event points are marked as 1, and fracturing continues. When the number of microseismic event points increases for the second time, this time is marked as 2, and the second microseismic event points are marked as 2. Fracturing continues, and the number of microseismic event points will continue to increase. Each time the number increases, the corresponding time is marked as 3, 4...N, and the corresponding microseismic event points corresponding to each time are also marked accordingly. Therefore, all the microseismic event points in this fracturing section are marked with corresponding serial numbers, from 1 to N. One serial number may correspond to multiple microseismic event points, and each serial number corresponds to a certain time in the fracturing process. Finally, all microseismic event points with the same serial number are connected into lines. The positions of these lines are the positions where the fractures exist, including hydraulic fractures and natural fractures.

[0066] (3) Based on the distribution of natural fractures around the wellbore, the microseismic event points corresponding to the natural fractures in the fractures around the wellbore are screened out;

[0067] The effective microseismic event point is a microseismic event point generated by a natural fracture that forms a fluid seepage channel with the wellbore.

[0068] The distribution of natural fractures around the wellbore is obtained through the FMI fracture interpretation results in step (1). As shown in Figure 2, the natural fractures are distributed in the northwest-southeast direction. The distribution of fractures around the wellbore represented by microseismic event points is obtained through step (2), including hydraulic fractures and natural fractures. Figure 3 As shown, therefore, the distribution of the strike of natural fractures around the wellbore can be obtained in step (1). Based on this, the microseismic event points generated by natural fractures are screened out from the microseismic event points generated by hydraulic fractures and natural fractures in step (2), that is, the microseismic event points whose connecting line is in the northwest-southeast direction. Figure 3 The microseismic event points marked as 4 to 8 in the figure lay the foundation for the next step of classification of microseismic event points.

[0069] (4) classifying the screened microseismic event points and screening out effective microseismic event points;

[0070] Combined with the fracturing construction curve, the microseismic event points that respond to natural fractures at the beginning, middle and end of fracturing are classified to screen out the microseismic event points related to the reservoir transformation range. The specific method is as follows:

[0071] The fracturing construction curve consists of three parts, namely, pumping pressure, construction displacement, and sand concentration. These three parts are used as the vertical coordinates and time is used as the horizontal coordinate to draw a curve graph. The core of these three curves is the pressure curve. By observing the pressure curve during fracturing construction, the underground crack situation can be understood. When a certain section starts fracturing, the time when the microseismic event point first appears is marked as 1, as shown in step (2). At the same time, the time position on the fracturing construction curve is marked as 1, as shown in step (2). Figure 4 As shown in the figure, the microseismic event point corresponding to this time has been marked as 1. When the number of microseismic event points increases for the second time, this time has been marked as 2. At the same time, the time position on the fracturing construction curve is marked as 2. The microseismic event point corresponding to this time has been marked as 2. The number of microseismic event points continues to increase, and the corresponding time has been marked as 3, 4...N. At the same time, the corresponding time on the fracturing construction curve is marked as 3, 4...N, so that the fracturing construction curve and the microseismic event point are linked with time as the medium. Each microseismic event point has a corresponding serial number. The serial number value represents the order of time. The larger the serial number value, the later the microseismic event point occurs. A serial number may correspond to multiple microseismic event points, but a serial number only corresponds to a certain time in the fracturing construction process, that is, a certain time on the fracturing construction curve.

[0072] According to the time when the microseismic event points on the fracturing construction curve appear, the microseismic event points are divided into three categories according to the beginning, middle and end of fracturing: Category A, microseismic event points that appear in the early stage of fracturing construction and far away from the wellbore perforation position. During this period, the fracturing fluid is continuously pumped into the wellbore, causing the wellbore pressure to be higher than the formation pressure. These microseismic event points are related to the shear slip of the distal fractures due to stress disturbance, but they do not connect with the hydraulic fractures, that is, they do not form a fluid seepage channel with the wellbore, and do not participate in the calculation of the reservoir transformation volume. They are invalid microseismic event points, that is, Figure 4 At the moment marked as 1, Figure 3 The microseismic event point marked as 1 in the figure is far away from the wellbore perforation position and does not form a fluid seepage channel with the wellbore, so it is an invalid event point; Category B, microseismic event points that appear along the direction of the maximum horizontal principal stress during the fracturing construction. During this period, the fracturing fluid continues to be pumped into the wellbore, the wellbore pressure is higher than the formation pressure, and the hydraulic fractures expand along the direction of the maximum horizontal principal stress. During the expansion process, they are captured by natural fractures, and shear slip occurs in the natural fractures to produce microseismic responses. These microseismic event points communicate with hydraulic fractures and form fluid seepage channels with the wellbore, and participate in the calculation of the reservoir transformation volume. They are effective microseismic event points, that is, Figure 4 The moments marked 2 to 5, Figure 3 The microseismic event points marked as 4 and 5 in the figure are connected to hydraulic fractures and form fluid seepage channels with the wellbore, which are effective event points; Class C, microseismic event points that appear after the fracturing construction is completed, during this period, the fracturing fluid stops being pumped into the wellbore, and there is a dynamic adjustment process between the wellbore pressure and the formation pressure. Finally, the two reach a state of equilibrium. The dynamic adjustment process of the wellbore pressure and the formation pressure will cause shear slippage of the natural fractures due to stress disturbance, thereby causing microseismic event points at the corresponding positions. These microseismic event points need to refer to the relative position relationship with the Class B microseismic event points to determine whether they are effective microseismic event points, that is, Figure 4 At the moments marked 6, 7, and 8, Figure 3 The microseismic event points marked as 6 and 7 are connected to the type B microseismic event points, that is, they form fluid seepage channels with the wellbore and participate in the calculation of reservoir transformation volume, and are effective event points; Figure 3 The microseismic event point marked as 8 in the figure is not connected to the type B microseismic event point, that is, it does not form a fluid seepage channel with the wellbore and does not participate in the calculation of the reservoir transformation volume. It is an invalid event point.

[0073] (5) Calculate the reservoir transformation volume based on effective microseismic event points.

[0074] Through (4) classification of microseismic event points generated by natural fractures, invalid microseismic event points generated by natural fractures that do not form fluid seepage channels with the wellbore are excluded, that is, microseismic event points that do not participate in the calculation of reservoir transformation volume, that is, Figure 3The event points marked as 1 and 8 in the figure are

[0075] The remaining effective microseismic event points are used to calculate the reservoir transformation volume. The effective microseismic event points include the microseismic event points generated by the natural fractures that form fluid seepage channels with the wellbore in step (4) and the microseismic event points generated during the expansion of the hydraulic fractures, that is, Figure 3 The microseismic event points are marked as 2 to 7. The reservoir transformation volume calculation method uses the octree algorithm of non-uniform grids. The algorithm is based on the octree method in computer graphics and is a multi-level tree grid structure that can fully consider the non-uniform distribution of point sets in density and generate non-uniform grids based on the density distribution. The tree structure can also better reflect the connectivity relationship of the spatial structure of microseismic event points. Figure 5a The microseismic event points of all the fracturing sections of a certain well are classified and screened to calculate the reservoir transformation volume. Figure 5b Schematic diagram of calculating reservoir transformation volume for a well. Figure 6 This is a comparison chart of the SRV of a well and the production capacity of different production systems. The two have a good correlation, which confirms the effectiveness of the microseismic event point classification method in calculating the reservoir transformation volume.

[0076] like Figure 7 As shown, the present invention also proposes a reservoir transformation volume calculation system, the system comprising:

[0077] The acquisition module is used to obtain the distribution of natural fractures around the wellbore.

[0078] A sorting module is used to sort the microseismic event points within the fracturing time period to obtain the distribution of cracks around the wellbore represented by the microseismic event points; the sorting module is used to sort the microseismic event points within the fracturing time period, including: sorting the microseismic event points into a digital sequence that occurs in sequence; connecting the microseismic event points at the same time into a line, and the position of the line is the position where the cracks around the wellbore exist.

[0079] The first screening module is used to screen out microseismic event points corresponding to natural cracks in the cracks around the wellbore based on the distribution of natural cracks around the wellbore, including: screening out natural cracks in the cracks around the wellbore according to the direction distribution of natural cracks around the wellbore; and selecting corresponding microseismic event points according to the natural cracks in the cracks around the wellbore.

[0080] The second screening module is used to classify the screened microseismic event points and screen out effective microseismic event points; the second screening module is used to classify the screened microseismic event points, including: based on the fracturing construction curve, classifying the screened microseismic event points according to the beginning, middle and after fracturing.

[0081] The calculation module is used to calculate the reservoir transformation volume according to the effective microseismic event points.

[0082] like Figure 8 As shown, an embodiment of the present invention provides a device for calculating reservoir transformation volume, the device comprising: a processor 101, a communication interface 102, a memory 103 and a communication bus 104, wherein the processor 101, the communication interface 102, and the memory 103 communicate with each other through the communication bus 104, and the memory 103 is used to store computer programs;

[0083] In one embodiment of the present invention, the processor 101 is used to implement the layer transformation volume calculation method provided by any one of the aforementioned method embodiments when executing the program stored in the memory 103.

[0084] The implementation principle and technical effect of the device provided in the embodiment of the present invention are similar to those of the above embodiment and will not be described in detail here.

[0085] The above-mentioned memory 103 can be an electronic memory such as a flash memory, an EEPROM (electrically erasable programmable read-only memory), an EPROM, a hard disk or a ROM. The memory 103 has a storage space for program codes for executing any method steps in the above-mentioned method. For example, the storage space for program codes may include various program codes for implementing various steps in the above method respectively. These program codes can be read from or written into one or more computer program products. These computer program products include program code carriers such as hard disks, compact disks (CDs), memory cards or floppy disks. Such computer program products are usually portable or fixed storage units. The storage unit may have a storage segment or storage space arranged similarly to the memory 103 in the above-mentioned electronic device. The program code can be compressed, for example, in an appropriate form. Generally, the storage unit includes a program for executing the method steps according to an embodiment of the present invention, that is, a code that can be read by a processor such as 101, which, when run by an electronic device, causes the electronic device to execute various steps in the method described above.

[0086] The embodiment of the present invention further provides a computer-readable storage medium. The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the layer transformation volume calculation method described above is implemented.

[0087] The computer-readable storage medium may be included in the device / apparatus described in the above embodiment; or it may exist independently without being assembled into the device / apparatus. The above computer-readable storage medium carries one or more programs, and when the above one or more programs are executed, the method according to the embodiment of the present invention is implemented.

[0088] According to an embodiment of the present invention, the computer-readable storage medium may be a non-volatile computer-readable storage medium, for example, may include but is not limited to: a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination thereof. In the present invention, the computer-readable storage medium may be any tangible medium containing or storing a program, which may be used by or in combination with an instruction execution system, apparatus, or device.

[0089] Those skilled in the art should understand that although the present invention has been described in detail with reference to the aforementioned embodiments, it is still possible to modify the technical solutions described in the aforementioned embodiments, or to make equivalent replacements for some of the technical features therein; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for calculating reservoir transformation volume, characterized in that: The method comprises: Obtain the distribution of natural fractures around the wellbore; The microseismic event points within the fracturing period are sorted out to obtain the distribution of cracks around the wellbore represented by the microseismic event points; Based on the distribution of natural fractures around the wellbore, the microseismic event points corresponding to the natural fractures in the fractures around the wellbore are screened out; Classifying the screened microseismic event points and screening out effective microseismic event points, wherein the effective microseismic event points are microseismic event points generated by natural fractures that form fluid seepage channels with the wellbore; The reservoir transformation volume is calculated based on the effective microseismic event points.

2. A reservoir transformation volume calculation method according to claim 1, characterized in that: The distribution includes fracture density, strike and dip.

3. A reservoir transformation volume calculation method according to claim 1, characterized in that: The microseismic event points during the fracturing period are sorted out, including: Arrange the microseismic event points into a digital sequence that occurs sequentially; Connect the microseismic event points at the same time into a line, and the position of the line is the location where the cracks around the wellbore exist.

4. A reservoir transformation volume calculation method according to claim 1, characterized in that: The fractures around the wellbore include hydraulic fractures and natural fractures.

5. A reservoir transformation volume calculation method according to claim 1, characterized in that: Based on the distribution of natural fractures around the wellbore, the microseismic event points corresponding to the natural fractures in the fractures around the wellbore are screened out, including: According to the distribution of the natural fractures around the wellbore, the natural fractures in the fractures around the wellbore are screened out; The corresponding microseismic event points are selected according to the natural fractures in the fractures around the wellbore.

6. A reservoir transformation volume calculation method according to claim 1, characterized in that: The screened microseismic event points are classified, including: based on the fracturing construction curve, the screened microseismic event points are classified according to the beginning of fracturing, during fracturing and after fracturing.

7. A reservoir transformation volume calculation method according to claim 6, characterized in that: The fracturing construction curve includes a pumping pressure curve, a construction displacement curve and a sand concentration curve.

8. A reservoir transformation volume calculation method according to claim 6, characterized in that: The microseismic event point initially formed by the fracturing is an invalid microseismic event point; The microseismic event points formed during the fracturing are effective microseismic event points; The microseismic event point formed after the fracturing needs to be judged as a valid microseismic event point according to the location of the microseismic event point.

9. A reservoir transformation volume calculation method according to claim 8, characterized in that: The method for determining the microseismic event point formed after the fracturing is as follows: If the position of the microseismic event point formed after fracturing is connected with the position of the microseismic event point formed during fracturing, it is a valid microseismic event point; otherwise, it is an invalid microseismic event point.

10. A reservoir transformation volume calculation method according to claim 1, characterized in that: The calculation method of the reservoir transformation volume is an octree algorithm of a non-uniform grid.

11. A reservoir transformation volume calculation system, characterized in that: The system comprises: An acquisition module, used to obtain the distribution of natural fractures around the wellbore; A sorting module is used to sort the microseismic event points within the fracturing time period to obtain the distribution of cracks around the wellbore represented by the microseismic event points; The first screening module is used to screen out microseismic event points corresponding to natural fractures in the fractures around the wellbore based on the distribution of natural fractures around the wellbore; The second screening module is used to classify the screened microseismic event points and screen out effective microseismic event points; The calculation module is used to calculate the reservoir transformation volume according to the effective microseismic event points.

12. A reservoir transformation volume calculation system according to claim 11, characterized in that: The sorting module is used to sort the microseismic event points within the fracturing time period, including: Arrange the microseismic event points into a digital sequence that occurs sequentially; Connect the microseismic event points at the same time into a line, and the position of the line is the location where the cracks around the wellbore exist.

13. A reservoir transformation volume calculation system according to claim 11, characterized in that: The first screening module is used to screen out microseismic event points corresponding to natural cracks in the cracks around the wellbore based on the distribution of natural cracks around the wellbore, including: According to the distribution of the natural fractures around the wellbore, the natural fractures in the fractures around the wellbore are screened out; The corresponding microseismic event points are selected according to the natural fractures in the fractures around the wellbore.

14. A reservoir transformation volume calculation system according to claim 11, characterized in that: The second screening module is used to classify the screened microseismic event points, including: Based on the fracturing construction curve, the selected microseismic event points are classified according to the beginning, middle and end of fracturing.

15. A reservoir transformation volume calculation device, characterized in that: The device comprises: a processor, a communication interface, a memory and a communication bus, wherein the processor, the communication interface and the memory communicate with each other via the communication bus; Memory; and storage of computer programs; A processor, wherein the processor is configured to execute the reservoir transformation volume calculation method according to any one of claims 1 to 10.

16. A machine-readable storage medium having instructions stored thereon, characterized in that: When the instruction is executed by a processor, the processor is configured to execute the reservoir reformation volume calculation method according to any one of claims 1 to 10.

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