Tight oil fracturing effect evaluation method, system, device and storage medium based on fracturing fluid flowback data

Abstract

The present invention provides a method, system, equipment, and storage medium for evaluating the effectiveness of tight oil fracturing based on fracturing fluid flowback data. This method utilizes the theory of unstable well testing to calculate a flowback diagnostic curve for a fractured horizontal well, combines this with a linear analysis method to calculate the effective fracture volume, and integrates actual operating conditions such as fracturing completion, sand production, and drilling plugs to comprehensively evaluate the effective fracture volume, resulting in a more accurate evaluation result. The fracturing effect evaluation method of the present invention is derived based on extensive theoretical analysis and fitting calculation verification, and has been validated by microseismic monitoring of example wells and long-term production data in the Mahu area of ​​Xinjiang. The results are reliable, the data is highly usable, economical, and easily accessible, and can be used to quickly and easily evaluate the fracturing effect and guide the optimization of fracturing parameters.

Description

Technical Field

[0001] The present invention relates to a fracturing technology in the field of petroleum development, and in particular to a method, system, equipment and storage medium for evaluating tight oil fracturing effects based on fracturing fluid flowback data. Background Art

[0002] Multi-stage horizontal well fracturing is a core technology for economically extracting tight oil and gas from Xinjiang oilfields. Fracturing effectiveness evaluation and fracture parameter inversion are key and challenging aspects of tight oil and gas development. Currently, methods have been developed, including field monitoring, operation pressure diagnosis, shut-in pressure drop fitting, and production performance analysis. Field monitoring relies on the accuracy of signal interpretation, requires supporting equipment, and is relatively costly. Operation pressure diagnosis and shut-in pressure drop fitting are based on conventional post-pressure assessment methods, which are subject to significant uncertainty and cannot assess fracture information after closure. Production performance analysis is a commonly used method for evaluating shale fracturing effectiveness, but it often requires six to eight months or even more than a year of production history. Fracturing fluid flowback data contains extensive fracture information and is highly cost-effective. Research has demonstrated its importance in unconventional oil and gas development. However, the importance and utilization of historical fracturing fluid flowback data in China are low.

[0003] Xinjiang oilfields boast a vast reservoir distribution (burial depths ranging from 2600 to 4500 m) and complex and diverse reservoir mineralogy (tuff, granite, andesite, mudstone, shale, etc.). This results in significant variations in fracturing effectiveness across blocks using similar fracturing techniques. Some horizontal wells exhibit prolonged post-fracturing drainage periods and high water content, resulting in waste from rapid fracturing fluid inflow and outflow. Therefore, developing fracturing effectiveness evaluation techniques based on historical flowback data is crucial. A review of various tight oil and gas reservoir flowback analysis models and evaluation methods established domestically and internationally aims to utilize flowback data to invert parameters such as effective fracture pore volume and fracture volume loss during flowback, thereby analyzing and evaluating fracturing effectiveness. However, these models are currently designed for the initial stage of flowback, using idealized flowback data and failing to consider the impact of actual operating conditions (such as sand production and drill plugging) on ​​fracturing effectiveness, directly impacting the accuracy of evaluation results. Therefore, research is urgently needed on tight oil fracturing effectiveness evaluation methods based on fracturing fluid flowback data to provide a reference for characterizing hydraulic fractures and evaluating post-fracturing effectiveness. Summary of the Invention

[0004] In response to the current lack of technical problems in accurately inverting hydraulic fracture parameters using backflow data, the purpose of the present invention is to provide a method, system, equipment and storage medium for evaluating the fracturing effect of tight oil based on fracturing fluid backflow data. This method takes into account the impact of actual working conditions (such as sand production, drill plug, etc.) on the fracturing effect, and the evaluation results are more accurate.

[0005] The present invention is achieved through the following technical solutions:

[0006] A method for evaluating tight oil fracturing effects based on fracturing fluid flowback data, comprising:

[0007] S1, obtaining bottomhole pressure and fluid discharge data during the flowback period, and calculating the normalized daily fluid production and normalized cumulative fluid production based on the preset value of the effective fracture volume;

[0008] S2, draw the flow pattern diagnostic curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis;

[0009] S3, obtain the coordinate value of the intersection of the extended line of the straight segment in the flow pattern diagnostic curve and the x-axis, calculate the effective fracture volume, and compare the calculated effective fracture volume with the preset effective fracture volume value in S1. If it does not meet the engineering accuracy requirements, use the calculated effective fracture volume as the new preset effective fracture volume value in S1, repeat S1-S3 until the engineering accuracy requirements are met, and output the effective fracture volume;

[0010] S4. If sand or plugging conditions exist, use the bottomhole pressure and drainage data during the flowback period to draw a double logarithmic curve of standardized pressure and material balance time. Identify the straight line segment with a slope of unity in the curve and obtain the slope value of the straight line segment by fitting in a linear coordinate system. Calculate the ratio of the slope values ​​before and after the sand or plugging node to obtain the change in effective fracture volume before and after sand or plugging.

[0011] Preferably, it also includes:

[0012] The total volume of fracturing fluid entering the well is obtained, and the ratio of the effective fracture volume to the total volume of fracturing fluid entering the well is calculated to obtain the fracturing fluid efficiency of the well to be evaluated.

[0013] Preferably, it also includes:

[0014] The total volume of proppant injected into the well is obtained, and the propped fracture volume is calculated. The difference between the effective fracture volume and the propped fracture volume is then calculated to obtain the unpropped fracture volume. The ratio of the unpropped fracture volume to the effective fracture volume is then calculated to obtain the fracture complexity of the well to be evaluated.

[0015] Furthermore, the volume of the propped fractures is 47.5% of the total volume of the proppant injected into the well.

[0016] Preferably, it also includes:

[0017] The linear analysis method is used to identify the fracture closure control stage in the flow pattern diagnostic curve. The cumulative fluid discharge volume from the well opening to the end of the fracture closure control stage is calculated. The ratio of the cumulative fluid discharge volume to the effective fracture volume is calculated to obtain the fracture closure degree of the well to be evaluated.

[0018] Preferably, in S1, the normalized daily liquid production and the normalized cumulative liquid production are calculated using a flow material balance method.

[0019] Preferably, in S1, the initial effective fracture volume is preset to 1 / 2 of the total volume of the fracturing fluid entering the well.

[0020] A tight oil fracturing effect evaluation system based on fracturing fluid flowback data, comprising:

[0021] A data acquisition module is used to obtain bottom hole pressure and discharge data during flowback;

[0022] The evaluation module is used to calculate the normalized daily liquid production and the normalized cumulative liquid production based on the preset value of the effective fracture volume; draw a flow diagnosis curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis; obtain the coordinate value of the intersection of the extension line of the straight line segment in the flow diagnosis curve and the x-axis, calculate the effective fracture volume, and compare the calculated effective fracture volume with the preset value of the effective fracture volume. If it does not meet the engineering accuracy requirements, the calculated effective fracture volume is used as the new preset value of the effective fracture volume, and it is iterated until the engineering accuracy requirements are met, and the effective fracture volume is output; if sand production or drilling plug conditions exist, the bottom hole pressure and drainage data during the backflow period are used to draw a double logarithmic curve of standardized pressure and material balance time, identify the straight line segment with a slope of unit 1 in the curve, and fit the slope value of the straight line segment in the linear coordinate system to calculate the ratio of the slope values ​​before and after the sand production or drilling plug node, and obtain the change in effective fracture volume before and after sand production or drilling plug.

[0023] A computer device comprises a memory, a processor and a computer program stored in the memory and executable on the processor, wherein the steps of the above method are implemented when the processor executes the computer program.

[0024] A computer-readable storage medium stores a computer program, which implements the steps of the above method when executed by a processor.

[0025] Compared with the prior art, the present invention has the following beneficial effects:

[0026] The present invention uses the unstable well test theory method to calculate the flowback flow diagnostic curve of the fractured horizontal well, combines the linear analysis method to calculate the effective fracture volume, and comprehensively evaluates the effective fracture volume based on the real working condition information such as fracturing completion, sand production and drilling plug, so that the evaluation result is more accurate. The fracturing effect evaluation method of the present invention is derived on the basis of a large amount of theoretical analysis and fitting calculation verification, and has been verified by microseismic monitoring of example wells in the Mahu area of ​​Xinjiang and long-term production data, and the results are reliable. The evaluation method of the present invention can use economical and convenient historical data on fracturing fluid flowback, comprehensively consider the real working conditions such as fracturing completion, sand production and drilling plug, and has high data utilization rate, economic and easy to obtain. The fracturing fluid flowback data before production can be used to quickly invert key information such as the effective fracture volume, and the fracturing effect can be evaluated quickly and conveniently, and the fracturing parameter optimization can be guided.

[0027] Furthermore, the present invention can also quantitatively evaluate the efficiency of fracturing fluid, the complexity of fractures, and the degree of fracture closure, providing a scientific basis and theoretical support for the optimization of on-site fracturing process parameters. This solves the problem that existing research only focuses on the evaluation of effective fracture volume, while ignoring fracturing effect indicators such as fracturing fluid efficiency, fracture complexity, and degree of closure. BRIEF DESCRIPTION OF THE DRAWINGS

[0028] Figure 1 This is a flow chart of the main method of the present invention;

[0029] Figure 2 Schematic diagram of flow pattern diagnosis curves of normalized daily liquid production and normalized cumulative liquid production according to the present invention;

[0030] Figure 3 Flow pattern diagnostic curves of the normalized daily liquid production and normalized cumulative liquid production of Well X of the present invention;

[0031] Figure 4 is a linear fitting curve of the standardized pressure and material equilibrium time of Well X of the present invention;

[0032] Figure 5 This is a comparison chart of the fracture volume evaluated by flowback data and the reconstruction volume interpreted by microseismic interpretation in the present invention;

[0033] Figure 6 This is a comparison chart of the liquid efficiency evaluated by short-term flowback data and long-term flowback rate data of the present invention. DETAILED DESCRIPTION

[0034] In order to further understand the present invention, the present invention is described below in conjunction with embodiments. These descriptions are only for further explaining the features and advantages of the present invention and are not intended to limit the claims of the present invention.

[0035] This invention provides a quantitative method for evaluating the fracturing effectiveness of horizontal tight oil wells, an original innovation patented method. By comprehensively considering real-world operating conditions such as fracturing completion, sand production, and drill plugging, it can quickly and effectively invert hydraulic fracture parameters, providing quantitative guidance for optimizing on-site fracturing and flowback process parameters.

[0036] Please refer to Figure 1 The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data of the present invention comprises:

[0037] Step 1: Data normalization

[0038] Obtain bottomhole pressure and fluid discharge data during the flowback period, use the flow material balance method to preset the initial effective fracture volume, and calculate the pressure-normalized daily fluid production and normalized cumulative fluid production;

[0039] Step 2: Drawing the flow diagnostic curve

[0040] Obtain the normalized daily and cumulative liquid production data, draw the flow pattern diagnosis curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis, and use the linear analysis method to identify the fracture closure control stage. Figure 2 , Figure 2 Schematic diagram of flow pattern diagnosis curve of normalized daily liquid production and normalized cumulative liquid production;

[0041] Step 3: Calculation of effective crack volume

[0042] Obtain the coordinate value of the intersection of the extended line of the straight segment in the flow diagnostic curve and the x-axis, calculate the effective fracture volume, and compare the calculated value with the preset effective fracture volume value in step 1. If it does not meet the engineering accuracy requirements, use the calculated value in step 1 as the new preset value, repeat steps 1-3 until the engineering accuracy requirements are met, and output the effective fracture volume;

[0043] Step 4: Analysis of sand production and drilling plug working conditions

[0044] If there is no sanding or drilling plugging condition, skip this step. If there is sanding or drilling plugging condition, use the bottom hole pressure and drainage data during the flowback period to draw a double logarithmic curve of standardized pressure and material balance time, identify the straight line segment with a slope of unit 1 in the curve, and fit the slope value of the straight line segment in the linear coordinate system. Calculate the ratio of the slope values ​​before and after the sanding or drilling plugging node to obtain the effective fracture volume change before and after the sanding or drilling plugging node.

[0045] Step 5: Calculation of fracturing fluid efficiency

[0046] Obtain the total volume of fracturing fluid entering the well, and calculate the ratio of the effective fracture volume to the total volume of fracturing fluid entering the well according to the definition of fracturing fluid efficiency to obtain the fracturing fluid efficiency of the well to be evaluated;

[0047] Step 6: Calculation of crack complexity

[0048] Obtain the total volume of proppant in the well. Based on the definition of unpropped fractures, calculate the difference between the effective fracture volume and the propped fracture volume (47.5% of the total volume of proppant in the well) to obtain the unpropped fracture volume. Then, based on the definition of fracture complexity, calculate the ratio of the unpropped fracture volume to the effective fracture volume to obtain the fracture complexity of the well to be evaluated.

[0049] Step 7: Calculation of crack closure degree

[0050] according to Figure 2 During the identified fracture closure control stage, the cumulative fluid discharge volume from the well opening to the end of this stage is calculated. Based on the definition of fracture closure degree, the ratio of the cumulative fluid discharge volume to the effective fracture volume is calculated to obtain the fracture closure degree of the well to be evaluated.

[0051] The fractured horizontal well in this embodiment is located in the tight conglomerate oil block in the Mahu area.

[0052] The embodiment of the present invention provides a method for evaluating the effect of tight oil fracturing based on fracturing fluid flowback data. The specific implementation process is as follows:

[0053] (1) Data normalization

[0054] Obtain bottomhole pressure and fluid discharge data during the flowback period, use the flow material balance method to preset the initial effective fracture volume (recommended to be 1 / 2 of the total volume of fracturing fluid entering the well), and calculate the pressure-normalized daily fluid production and normalized cumulative fluid production;

[0055] (2) Flow state diagnostic curve drawing

[0056] Obtain the normalized daily and cumulative liquid production data, draw the flow pattern diagnosis curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis, and use the linear analysis method to identify the fracture closure control stage, see Figure 3 , Figure 3 The flow pattern diagnostic curves of the normalized daily liquid production and normalized cumulative liquid production of Well X;

[0057] (3) Calculation of effective crack volume

[0058] Obtain the coordinate value of the intersection of the straight line extension line and the x-axis in the flow state diagnostic curve, calculate the effective crack volume, and compare the calculated value with the preset value of the effective crack volume in step 1. If it does not meet the engineering accuracy requirements, use the calculated value of this step as the new effective crack volume preset value of step (1), and repeat steps (1) to (3) until the engineering accuracy requirements are met. The output effective crack volume is 11500.0m 3 ;

[0059] (4) Analysis of sand production and drilling plug working conditions

[0060] refer to Figure 4 Well X, the well to be evaluated, has sand production and plugging conditions. Using the bottomhole pressure and drainage data during the flowback period, a double logarithmic curve of standardized pressure and material balance time was drawn. A straight line segment with a slope of unit 1 in the curve was identified and fitted in a linear coordinate system to obtain the slope value of the straight line segment. The ratio of the slope values ​​before and after the sand production node was calculated to be 92.6%, indicating that the effective fracture volume decreased by 847.4 m after sand production. 3 The ratio of the slope values ​​before and after the drilling plug is calculated to be 111.8%, and the effective fracture volume after drilling plug is 1256.6m 3 ;

[0061] (5) Calculation of fracturing fluid efficiency

[0062] The total volume of fracturing fluid injected into the well is 43171.4m 3 According to the definition of fracturing fluid efficiency, the ratio of effective fracture volume to the total volume of fracturing fluid injected into the well is calculated, and the fracturing fluid efficiency of the evaluated well X is 26.6%.

[0063] (6) Calculation of crack complexity

[0064] The total volume of proppant injected into the well is 7150.0m 3 According to the definition of unsupported cracks, the effective crack volume and the supported crack volume (3396.3m 3 ), the unsupported crack volume is 8103.7m 3 , and then according to the definition of fracture complexity, the ratio of unsupported fracture volume to effective fracture volume is calculated, and the fracture complexity of the well to be evaluated is obtained to be 70.5%;

[0065] (7) Calculation of crack closure degree

[0066] according to Figure 3 The identified fracture closure control stage, the cumulative wellhead discharge volume from well opening to the end of this stage is calculated to be 1758.8m 3 According to the definition of fracture closure degree, the ratio of the cumulative drainage volume to the effective fracture volume was calculated, and the fracture closure degree of the well to be evaluated was obtained to be 15.3%.

[0067] The microseismic monitoring and long-term production data of some fractured wells in the Mahu area were used to verify the change trend of the method interpretation results and the microseismic interpretation results (see Figure 5 ), the fracturing fluid efficiency evaluated by short-term flowback data is consistent with the flowback rate trend reflected by long-term production data (see Figure 6), which proves the effectiveness of the method, so the present invention has broad application prospects.

[0068] The present invention also provides a tight oil fracturing effect evaluation system based on fracturing fluid flowback data, comprising:

[0069] A data acquisition module is used to obtain bottom hole pressure and discharge data during flowback;

[0070] The evaluation module is used to calculate the normalized daily liquid production and the normalized cumulative liquid production based on the preset value of the effective fracture volume; draw a flow diagnosis curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis; obtain the coordinate value of the intersection of the extension line of the straight line segment in the flow diagnosis curve and the x-axis, calculate the effective fracture volume, and compare the calculated effective fracture volume with the preset value of the effective fracture volume. If it does not meet the engineering accuracy requirements, the calculated effective fracture volume is used as the new preset value of the effective fracture volume, and it is iterated until the engineering accuracy requirements are met, and the effective fracture volume is output; if sand production or drilling plug conditions exist, the bottom hole pressure and drainage data during the backflow period are used to draw a double logarithmic curve of standardized pressure and material balance time, identify the straight line segment with a slope of unit 1 in the curve, and fit the slope value of the straight line segment in the linear coordinate system to calculate the ratio of the slope values ​​before and after the sand production or drilling plug node, and obtain the change in effective fracture volume before and after sand production or drilling plug.

[0071] One embodiment of the present invention provides a computer device. The computer device of this embodiment includes: a processor, a memory, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of each of the aforementioned method embodiments are implemented. Alternatively, when the processor executes the computer program, the functions of each module / unit in each of the aforementioned apparatus embodiments are implemented.

[0072] The computer program may be divided into one or more modules / units, which are stored in the memory and executed by the processor to accomplish the present invention.

[0073] The computer device may be a desktop computer, a notebook computer, a PDA, a cloud server, etc. The computer device may include, but is not limited to, a processor and a memory.

[0074] The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc.

[0075] The memory may be used to store the computer programs and / or modules, and the processor implements various functions of the computer device by running or executing the computer programs and / or modules stored in the memory and calling the data stored in the memory.

[0076] If the module / unit integrated in the computer device is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the present invention implements all or part of the process in the above-mentioned embodiment method, and can also be completed by instructing the relevant hardware through a computer program. The computer program can be stored in a computer-readable storage medium. When the computer program is executed by a processor, it can implement the steps of each of the above-mentioned method embodiments. Among them, the computer program includes computer program code, and the computer program code can be in source code form, object code form, executable file or some intermediate form. The computer-readable medium may include: any entity or device capable of carrying the computer program code, recording medium, USB flash drive, mobile hard disk, magnetic disk, optical disk, computer memory, read-only memory (ROM), random access memory (RAM), electric carrier signal, telecommunication signal and software distribution medium. It should be noted that the content contained in the computer-readable medium can be appropriately increased or decreased according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable media do not include electric carrier signals and telecommunication signals.

[0077] The above are merely preferred embodiments of the present invention and are not intended to limit the present invention. Those skilled in the art will readily appreciate that various modifications and variations of the present invention are possible. Any modifications, equivalent substitutions, or improvements made within the spirit and principles of the present invention shall be included within the scope of protection of the present invention.

Claims

1. A method for evaluating tight oil fracturing effect based on fracturing fluid flowback data, characterized in that: include: S1, obtaining bottomhole pressure and fluid discharge data during the flowback period, and calculating the normalized daily fluid production and normalized cumulative fluid production based on the preset value of the effective fracture volume; S2, draw the flow pattern diagnostic curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis; S3, obtain the coordinate value of the intersection of the extended line of the straight segment in the flow state diagnostic curve and the x-axis, calculate the effective fracture volume, and compare the calculated effective fracture volume with the preset effective fracture volume value in S1. If it does not meet the engineering accuracy requirements, use the calculated effective fracture volume as the new preset effective fracture volume value in S1, repeat S1-S3 until the engineering accuracy requirements are met, and output the effective fracture volume; S4. If sand or plugging conditions exist, use the bottomhole pressure and drainage data during the flowback period to draw a double logarithmic curve of standardized pressure and material balance time. Identify the straight line segment with a slope of unity in the curve and obtain the slope value of the straight line segment by fitting in a linear coordinate system. Calculate the ratio of the slope values ​​before and after the sand or plugging node to obtain the change in effective fracture volume before and after sand or plugging.

2. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 1, wherein: Also includes: The total volume of fracturing fluid entering the well is obtained, and the ratio of the effective fracture volume to the total volume of fracturing fluid entering the well is calculated to obtain the fracturing fluid efficiency of the well to be evaluated.

3. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 1, wherein: Also includes: The total volume of proppant injected into the well is obtained, and the propped fracture volume is calculated. The difference between the effective fracture volume and the propped fracture volume is then calculated to obtain the unpropped fracture volume. The ratio of the unpropped fracture volume to the effective fracture volume is then calculated to obtain the fracture complexity of the well to be evaluated.

4. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 3, wherein: The volume of propped fractures is 47.5% of the total volume of proppant injected into the well.

5. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 1, wherein: Also includes: The linear analysis method is used to identify the fracture closure control stage in the flow pattern diagnostic curve. The cumulative fluid discharge volume from the well opening to the end of the fracture closure control stage is calculated. The ratio of the cumulative fluid discharge volume to the effective fracture volume is calculated to obtain the fracture closure degree of the well to be evaluated.

6. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 1, wherein: In S1, the normalized daily liquid production and the normalized cumulative liquid production are calculated using the flow material balance method.

7. The method for evaluating tight oil fracturing effect based on fracturing fluid flowback data according to claim 1, wherein: In S1, the initial effective fracture volume is preset to 1 / 2 of the total volume of the fracturing fluid entering the well.

8. A tight oil fracturing effect evaluation system based on fracturing fluid flowback data, characterized in that: include: A data acquisition module is used to obtain bottom hole pressure and discharge data during flowback; The evaluation module is used to calculate the normalized daily liquid production and the normalized cumulative liquid production based on the preset value of the effective fracture volume; draw a flow diagnosis curve with the normalized daily liquid production as the y-axis and the normalized cumulative liquid production as the x-axis; obtain the coordinate value of the intersection of the extension line of the straight line segment in the flow diagnosis curve and the x-axis, calculate the effective fracture volume, and compare the calculated effective fracture volume with the preset value of the effective fracture volume. If it does not meet the engineering accuracy requirements, the calculated effective fracture volume is used as the new preset value of the effective fracture volume, and it is iterated until the engineering accuracy requirements are met, and the effective fracture volume is output; if sand production or drilling plug conditions exist, the bottom hole pressure and drainage data during the backflow period are used to draw a double logarithmic curve of standardized pressure and material balance time, identify the straight line segment with a slope of unit 1 in the curve, and fit the slope value of the straight line segment in the linear coordinate system to calculate the ratio of the slope values ​​before and after the sand production or drilling plug node, and obtain the change in effective fracture volume before and after sand production or drilling plug.

9. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the method according to any one of claims 1 to 7 are implemented.

10. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the steps of the method according to any one of claims 1 to 7 are implemented.

Images