Processing method, device and computer program product based on microseismic monitoring

Abstract

The microseismic monitoring-based processing method, device, and computer program product disclosed herein screen first effective microseismic events and determine their parameter information. This information is then used to determine an intersection chart representing the parameter information of the first effective microseismic events and first engineering parameters. Second engineering parameters can then be determined based on the intersection chart. If the second engineering parameters meet the requirements, they are used to guide the next stage of engineering construction. If the second engineering parameters meet the requirements, the engineering parameters can be dynamically adjusted in real time. This reduces the computational workload of on-site personnel and improves drawing efficiency. It also helps engineering technicians make rapid decisions based on comprehensive changes in fracturing curves.

Description

Technical Field

[0001] This disclosure relates to the field of microseismic monitoring technology, and in particular to processing methods, equipment and computer program products based on microseismic monitoring. Background Technology

[0002] In oil reservoir exploration and development, hydraulic fracturing is a key technology for improving the recovery rate and even the success rate of production wells. The effectiveness of hydraulic fracturing is generally evaluated by monitoring the resulting microseismic events. The occurrence and fracturing energy of microseismic events are strongly correlated with the geological characteristics of the rock formations traversed by the oil and gas well, such as fracture development, the magnitude and direction of in-situ stress, and the brittleness index. Therefore, analyzing microseismic events is of great significance for guiding the adjustment of fracturing engineering parameters.

[0003] Currently, the interpretation of microseismic data often relies on manual interpretation by technical personnel. This process is time-consuming, lacks comprehensive analysis, depends on the experience of the interpreters, and often leads to inconsistent conclusions among different personnel. Therefore, a convenient and efficient method is needed to reflect the relationship between fracturing engineering parameters and microseismic monitoring results. Summary of the Invention

[0004] This disclosure provides a processing method, equipment, and computer program product based on microseismic monitoring. It determines a first effective microseismic event and, based on the parameter information of the first effective microseismic event, establishes a correspondence between the parameter information of the first effective microseismic event and first engineering parameters. Therefore, this correspondence allows for a rapid and convenient reflection of the relationship between fracturing engineering parameters and microseismic monitoring results, thereby facilitating guidance for engineering construction.

[0005] In one aspect, this embodiment provides a processing method based on microseismic monitoring, the method comprising: determining a first effective microseismic event; determining parameter information of the first effective microseismic event based on the first effective microseismic event; and determining the correspondence between the parameter information of the first effective microseismic event and a first engineering parameter based on the parameter information of the first effective microseismic event.

[0006] In embodiments of this disclosure, determining a first valid microseismic event includes: determining the first valid microseismic event based on b-value analysis and / or time-offset intersection analysis.

[0007] In this embodiment of the disclosure, the parameter information of the first effective microseismic event includes at least one or more of the following: the number of occurrences of the first effective microseismic event, the frequency, the seam network extension speed, and the seam network complexity.

[0008] In the embodiments of this disclosure, determining the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter based on the parameter information of the first effective microseismic event includes: determining the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameter based on the parameter information of the first effective microseismic event and the first engineering parameter; wherein, the first engineering parameter includes at least one or more of the following: displacement, pressure, liquid volume, sand ratio, and viscosity.

[0009] In embodiments of this disclosure, the processing method further includes: determining second engineering parameters based on the intersection chart of parameter information of the first effective microseismic event and the first engineering parameters; wherein the second engineering parameters include at least one or more of the following: discharge rate, pressure, liquid volume, sand ratio, viscosity, and temporary plugging timing.

[0010] In embodiments of this disclosure, the processing method further includes: determining a second effective microseismic event based on the second engineering parameters; determining whether the second effective microseismic event meets a first preset condition; and determining the second engineering parameters as actual adjustment engineering parameters in response to the second effective microseismic event meeting the first preset condition.

[0011] In embodiments of this disclosure, the processing method further includes: determining a third engineering parameter in response to the second effective microseismic event not meeting a first preset condition; determining a third effective microseismic event based on the third engineering parameter; and determining whether the third effective microseismic event meets the first preset condition.

[0012] On the other hand, embodiments of this disclosure provide a computer device including a memory, a processor, and a computer program stored in the memory, wherein the processor executes the computer program to implement the steps of a processing method.

[0013] On the other hand, embodiments of this disclosure provide a computer-readable storage medium having a computer program stored thereon, wherein the computer program, when executed by a processor, implements the steps of a processing method.

[0014] On the other hand, embodiments of this disclosure provide a computer program product, including a computer program, which, when executed by a processor, implements the steps of a processing method.

[0015] This disclosure provides a processing method, equipment, and computer program product based on microseismic monitoring. It filters first effective microseismic events and determines their parameter information. This information is then used to determine an intersection chart representing the relationship between the parameter information of the first effective microseismic events and first engineering parameters. Second engineering parameters can then be determined based on the intersection chart. If the second engineering parameters meet the requirements, they are used to guide the construction of the next stage of the project. If the second engineering parameters do not meet the requirements, the engineering parameters can be dynamically adjusted in real time. This reduces the computational workload of on-site personnel and improves drawing efficiency. It also helps engineering technicians make rapid decisions based on changes in the intersection chart. Attached Figure Description

[0016] The present disclosure will be described in more detail below based on embodiments and with reference to the accompanying drawings:

[0017] Figure 1 The schematic diagram illustrates an environmental application according to an embodiment of the present disclosure.

[0018] Figure 2 A flowchart illustrating a processing method based on microseismic monitoring according to an embodiment of the present disclosure is shown.

[0019] Figure 3 A flowchart illustrating another processing method based on microseismic monitoring according to an embodiment of the present disclosure is shown.

[0020] Figure 4 The diagram illustrates the determination of the first effective microseismic event using the b-value analysis method according to an embodiment of the present disclosure.

[0021] Figure 5 The diagram illustrates the determination of the first effective microseismic event using the time-offset intersection analysis method according to an embodiment of the present disclosure.

[0022] Figure 6 The diagram illustrates the relationship between the flank sweep length and sweep depth of a first effective microseismic event according to an embodiment of the present disclosure.

[0023] Figure 7 A schematic diagram illustrating the relationship between the number of first effective microseismic events and the fracturing fluid volume according to an embodiment of the present disclosure is provided.

[0024] Figure 8 The diagram illustrates the relationship between the number of first effective microseismic events and fracturing time according to an embodiment of the present disclosure.

[0025] Figure 9 A schematic diagram illustrating the relationship between the crack propagation velocity of a first effective microseismic event according to an embodiment of the present disclosure is provided.

[0026] Figure 10 The diagram illustrates the relationship between the fracturing fluid volume in each fracturing segment and the length of the first effective microseismic event according to an embodiment of the present disclosure.

[0027] Figure 11 The diagram illustrates the relationship between the number of first effective microseismic events, event energy, and fracture length at different hydraulic fracturing stages according to embodiments of the present disclosure.

[0028] Figure 12 The schematic diagram illustrates the relationship between the two wing sweep lengths during different temporary plugging stages of hydraulic fracturing according to embodiments of the present disclosure.

[0029] Figure 13 The diagram illustrates the relationship between displacement and pressure corresponding to a first effective microseismic event according to an embodiment of the present disclosure.

[0030] Figure 14 The diagram illustrates the relationship between the number of perforation clusters in each section of a hydraulically fractured well and the number of first effective microseismic events according to an embodiment of the present disclosure.

[0031] Figure 15 The diagram illustrates the relationship between the fluid volume in each section of a hydraulically fractured well and the swept volume of a first effective microseismic event according to an embodiment of the present disclosure.

[0032] Figure 16 The diagram illustrates the relationship between the fluid volume in each section of a hydraulically fractured well and the swept fracture length of a first effective microseismic event according to an embodiment of the present disclosure.

[0033] Figure 17 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the number of first effective microseismic events according to an embodiment of the present disclosure.

[0034] Figure 18 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the swept volume of a first effective microseismic event according to an embodiment of the present disclosure.

[0035] Figure 19 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture length of a first effective microseismic event according to an embodiment of the present disclosure.

[0036] Figure 20 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture width of a first effective microseismic event, according to an embodiment of the present disclosure.

[0037] Figure 21A block diagram of a computer device according to an embodiment of the present disclosure is shown schematically.

[0038] Figure 22 A block diagram illustrating a computer-readable storage medium according to an embodiment of the present disclosure is shown.

[0039] Figure 23 A block diagram illustrating a computer program product according to an embodiment of the present disclosure is shown schematically. Detailed Implementation

[0040] To enable those skilled in the art to better understand the technical solutions of this disclosure, and to fully understand and implement the process of how this disclosure applies technical means to solve technical problems and achieve corresponding technical effects, the technical solutions in the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this disclosure, not all embodiments. The embodiments of this disclosure and the various features within them can be combined with each other without conflict, and the resulting technical solutions are all within the protection scope of this disclosure. All other embodiments obtained by those skilled in the art based on the embodiments of this disclosure without creative effort should fall within the protection scope of this disclosure.

[0041] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0042] It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases the steps shown or described may be executed in a different order than that shown here.

[0043] Figure 1 The schematic diagram illustrates an environmental application according to an embodiment of the present disclosure.

[0044] like Figure 1As shown, the microseismic monitoring system 100 may include a network device 101 and a monitoring device 102.

[0045] Network device 101 can receive data information sent by monitoring device 102. Monitoring device 102 can be responsible for converting ground motion caused by seismic waves into electrical or optical signals. Network device 101 can be a mobile device, tablet device, laptop computer, workstation, etc. Monitoring device 102 can be a seismograph, accelerometer, strain sensor, etc.

[0046] In some cases, a large number of highly sensitive monitoring devices 102, such as geophones or sensors, can be deployed around the monitoring area. During hydraulic fracturing, when geological media such as rocks are subjected to stress and fracture or deform, elastic waves, i.e., seismic waves, are released. These seismic waves propagate through the underground medium at different speeds and along different paths. The monitoring devices 102 can convert the received seismic wave signals into electrical or optical signals and record information such as the arrival time, amplitude, and frequency of the seismic waves. The monitoring devices 102 can then transmit the data to the network device 101.

[0047] Network device 101 can analyze and mine monitoring data, examining the correlation between fracturing engineering parameters and microseismic monitoring results during hydraulic fracturing. This helps engineers make rapid decisions at the fracturing site based on microseismic events and changes in the fracturing curve. It allows for real-time adjustments to key parameters such as fracturing displacement, fluid volume, and temporary plugging timing, thereby optimizing fracturing engineering parameters, selecting economical and reasonable fracturing schemes, and better leveraging the role of microseismic monitoring.

[0048] Figure 2 A flowchart illustrating a processing method based on microseismic monitoring according to an embodiment of the present disclosure is shown.

[0049] like Figure 2 As shown, the processing method of this embodiment includes steps S201, S202, and S203:

[0050] S201. Identify the first valid microseismic event.

[0051] In the embodiments of this disclosure, an effective microseismic event can refer to the elastic wave generated when geological media such as rocks fracture or deform due to hydraulic fracturing or other construction methods. During the operation, microseismic activity throughout the entire operation area can be continuously monitored through monitoring stations, and a series of microseismic events can be acquired. The acquired series of microseismic events also includes microseismic events caused by natural fracture activity. Therefore, in the embodiments of this disclosure, a first effective microseismic event can be selected from the series of microseismic events to eliminate the influence of microseismic events caused by natural fracture activity.

[0052] In the embodiments of this disclosure, the first effective microseismic events can be selected based on their temporal characteristics. For example, based on the start and end times of the hydraulic fracturing operation, microseismic events occurring within that start and end time period can be selected as the first effective microseismic events. Alternatively, the first effective microseismic events can be selected based on their spatial characteristics. For example, based on the spatial location information of a series of microseismic events, microseismic events located around the wellbore in the hydraulic fracturing design and in the expected fracture propagation direction can be selected as the first effective microseismic events.

[0053] In embodiments of this disclosure, the first effective microseismic event can also be determined based on b-value analysis and / or time-offset intersection analysis.

[0054] In the embodiments of this disclosure, a series of microseismic events can be analyzed using b-value analysis to select the first valid microseismic event. The b-value analysis method uses the Gutenberg-Richard relation, which describes the frequency-magnitude distribution in seismology, to calculate the b-value of microseismic events during the fracturing stage, and utilizes the variation characteristics of the b-value to identify whether fault activation occurs during the fracturing process.

[0055] In seismology, the b-value is commonly used to characterize the failure mode of seismic events. If the b-value of a region is close to 1, it is generally considered that a natural fault in that region has undergone shear activation. The frequency distribution characteristics of microseismic events can help determine whether the microseismic events under study are caused by the fracturing of existing rock structures or the movement of geological formations and landforms. The frequency-magnitude relationship (GR relationship) is as follows:

[0056] log 10 N M =a-bM

[0057] In the above formula, M represents the magnitude of the microseismic event, and N... M This represents the cumulative number of events with a magnitude less than M. Based on M and N... M The slope 'b' is obtained through fitting, i.e., b-value analysis, with b-values ​​typically ranging from 1 to 2. Different b-values ​​reveal the expected number of earthquake swarms and their possible magnitudes. Worldwide studies on b-values ​​show that the b-value for tectonic earthquakes is usually close to 1.0, while the b-value for artificially fractured earthquakes ranges from around 2. This reflects that artificially fractured earthquakes will produce more smaller earthquakes than tectonic activity.

[0058] In embodiments of this disclosure, a series of microseismic events can also be analyzed using a time-offset intersection analysis method to select the first effective microseismic event. The time-offset intersection analysis method first creates an intersection diagram of the event's offset from the perforation versus time, using the size of the circles to represent the event intensity. Through linear fitting analysis of the distance between the fracture front and the fracturing point over time, microseismic events involving natural fracture activity are identified. Dry events (often caused by abnormal fracture growth rates, usually occurring before fracturing fluid reaches the area) are eliminated, thus obtaining effective microseismic events caused by fracturing stimulation, and thereby roughly estimating the fracturing fluid distribution range.

[0059] According to embodiments of this disclosure, the first valid microseismic event can be accurately selected from a series of microseismic events using b-value analysis and / or time-offset intersection analysis. This minimizes the impact of natural fracture activity on microseismic events, thereby improving the accuracy of analysis and assessment of hydraulic fracturing and other related engineering conditions.

[0060] S202. Based on the first effective microseismic event, determine the parameter information of the first effective microseismic event.

[0061] In this embodiment of the disclosure, the parameter information of the first effective microseismic event can be calculated using the occurrence time and spatial location of the first effective microseismic event. For example, the spatial location coordinates of the first effective microseismic event can be obtained through monitoring stations. For instance, the specific location coordinates (X, Y, X) of a certain first effective microseismic event... i Y i Z i Based on the specific location coordinates (X...) i Y i Z i This allows us to determine parameters such as the fracture network extension rate of the first effective microseismic event.

[0062] In the embodiments of this disclosure, the parameter information of the first effective microseismic event includes at least one or more of the following: the number of occurrences of the first effective microseismic event, the frequency, the seam network extension speed, and the seam network complexity.

[0063] In the embodiments of this invention, the stitch mesh extension length and extension speed can be obtained using the following formula. It is understood that other parameter information of the first effective microseismic event can be obtained using other formulas, and no limitation is made here.

[0064] Formula for calculating the extension length of the mesh:

[0065]

[0066] Formula for calculating extension speed:

[0067]

[0068] In the formula, P i (x i y i , z i Let T be the spatial coordinates of the i-th microseismic point. i Let be the occurrence time of the i-th microseismic point. When i = 0, take the coordinates of the center point of the perforation in this segment as P0(x0, y0, z0), and T0 as the fracturing start time.

[0069] According to embodiments of this disclosure, by determining the parameter information of the first effective microseismic event, the spatial distribution of the first effective microseismic event can be determined. This, in turn, provides data support and decision-making basis for a deeper understanding of the fracture network characteristics formed by hydraulic fracturing and for evaluating fracturing effectiveness.

[0070] S203. Based on the parameter information of the first effective microseismic event, determine the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter.

[0071] In the embodiments of this disclosure, after determining the parameter information of the first effective microseismic event, a first engineering parameter can also be determined. The first engineering parameter may include, for example, displacement (the volume of liquid injected per unit time, commonly expressed in cubic meters per minute), pressure (including pressure values ​​at different locations such as wellhead pressure and bottom hole pressure, generally in megapascals), fluid volume (the total amount of liquid injected during the entire construction process, in cubic meters), proppant ratio (the ratio of proppant mass to fracturing fluid mass, commonly expressed as a percentage), viscosity (the viscosity of the fracturing fluid, in units such as millipascals per second), etc.

[0072] In the embodiments of this disclosure, the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter can also be determined. For example, during hydraulic fracturing, the frequency of occurrence of the first effective microseismic event changes over time. Simultaneously, the change in discharge rate during this period can be determined. Therefore, a correspondence between discharge rate and the frequency of occurrence of the first effective microseismic event can be established. Through this correspondence, the synchronization relationship between the frequency of occurrence of the first effective microseismic event and the discharge rate can be determined. For example, by checking whether the upward or downward trend of the frequency curve of the first effective microseismic event matches the trend of the discharge rate curve, if the frequency of occurrence of the first effective microseismic event also increases synchronously when the discharge rate increases, then a positive correlation between the two can be determined.

[0073] Furthermore, the spatial location of the first effective microseismic event can be determined, along with the spatial location of the perforation in the first engineering parameters. The number of first effective microseismic events can also be determined, along with the pressure in the first engineering parameters. And so on, without limitation.

[0074] In the embodiments of this disclosure, the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter can be a table, a time series cross plot, a scatter plot, or other methods that can reflect the relationship between the two, and there are no limitations on this.

[0075] According to embodiments of this disclosure, by screening first effective microseismic events and determining the parameter information of the first effective microseismic events, as well as determining the correspondence between the parameter information of the first effective microseismic events and first engineering parameters, the parameter information is quantified, which can reduce the workload of on-site interpretation technicians. Furthermore, it facilitates engineers in conveniently and quickly finding the relationship between the first engineering parameters of hydraulic fracturing and the microseismic monitoring results, and rapidly feeding this information back to the hydraulic fracturing project site.

[0076] Figure 3 A flowchart illustrating another processing method based on microseismic monitoring according to an embodiment of the present disclosure is shown.

[0077] like Figure 3 As shown, the processing method of this embodiment includes steps S301-S307:

[0078] S301. Identify the first valid microseismic event.

[0079] S302. Based on the first effective microseismic event, determine the parameter information of the first effective microseismic event.

[0080] S303. Based on the parameter information of the first effective microseismic event and the first engineering parameter, determine the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameter; wherein, the first engineering parameter includes at least one or more of the following: displacement, pressure, liquid volume, sand ratio, and viscosity.

[0081] In the embodiments of this disclosure, a convergence plot can be determined based on the parameter information of the first effective microseismic event and the first engineering parameters. The convergence plot may include a time-series convergence plot, a scatter plot, a three-dimensional plot, etc., simultaneously presenting the parameter information of the first effective microseismic event and the first engineering parameters on a single plot, thereby clearly demonstrating the inherent relationship between them.

[0082] According to embodiments of this disclosure, by determining the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameters, it helps engineering technicians to make quick decisions at the hydraulic fracturing site based on the first effective microseismic event and changes in the intersection chart.

[0083] S304. Based on the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameter, determine the second engineering parameter; wherein the second engineering parameter includes at least one or more of the following: discharge rate, pressure, liquid volume, sand ratio, viscosity, and temporary plugging timing.

[0084] In embodiments of this disclosure, the second engineering parameter may represent the construction engineering parameters that need to be set when carrying out the next construction project. For example, the displacement, pressure, etc., required when carrying out the next construction project.

[0085] In the embodiments of this disclosure, the second engineering parameters to be implemented can be determined based on the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameters. For example, the intersection chart can be a scatter plot reflecting the complexity of the fractures. If the first effective microseismic events in a certain area show a relatively regular and singular linear distribution, it indicates that the fractures may be relatively simple and have a relatively regular main fracture morphology. However, if the first effective microseismic events in a certain area show a complex distribution such as multiple obvious clusters, it means that the fractures have many branches. Therefore, according to the scatter plot reflecting the complexity of the fractures, a pressure lower than the pressure in the first engineering parameters can be set in the cluster area of ​​the first effective microseismic events to carry out hydraulic fracturing.

[0086] According to embodiments of this disclosure, key engineering parameters such as fracturing displacement, fluid volume, and temporary plugging timing can be quickly adjusted based on a determined intersection chart to select an economical and reasonable hydraulic fracturing scheme, thereby better leveraging the role of microseismic monitoring.

[0087] S305. Based on the second engineering parameters, determine the second effective microseismic event.

[0088] In the embodiments of this disclosure, a second effective microseismic event is determined by defining a second set of engineering parameters. Determining the second effective microseismic event may refer to simulating or calculating a second effective microseismic event based on the second engineering parameters.

[0089] In the embodiments of this disclosure, the number, frequency, mesh extension speed, and mesh complexity of the second effective microseismic events can be determined, and the adjusted microseismic event change characteristics can be determined based on the second effective microseismic events.

[0090] S306. Determine whether the second effective microseismic event meets the first preset condition.

[0091] In the embodiments of this disclosure, the first preset condition can be a pre-set condition that meets engineering requirements. For example, according to engineering requirements, the first preset condition is that at least 70% of the second effective microseismic events occur in the core area of ​​the project. It is understood that the first preset condition can also be other conditions, which are not limited here.

[0092] S307a. In response to the second effective microseismic event satisfying the first preset condition, the second engineering parameter is determined as the actual adjusted engineering parameter.

[0093] In the embodiments of this disclosure, the adjusted microseismic event variation characteristics can be determined based on the second effective microseismic event, and the rationality of the second engineering parameter can be verified accordingly. If rational, the second engineering parameter can be determined as the actual adjusted engineering parameter for the next engineering construction.

[0094] S307b, In response to the second effective microseismic event not meeting the first preset condition, determine the third engineering parameter.

[0095] In embodiments of this disclosure, if the second effective microseismic event does not meet the first preset condition, the third engineering parameter can be redefined. It is understood that the third engineering parameter may also include one or more of the following: displacement, pressure, liquid volume, sand ratio, viscosity, and temporary plugging timing.

[0096] In embodiments of this disclosure, a third effective microseismic event can also be determined based on the redefined third engineering parameters. It is then determined whether the third effective microseismic event meets a first preset condition. If the third effective microseismic event meets the first preset condition, the third engineering parameter can be determined as the actual adjusted engineering parameter. If the third effective microseismic event does not meet the first preset condition, a fourth engineering parameter can be redefined, and so on, until an engineering parameter that meets the first preset condition is found.

[0097] According to embodiments of this disclosure, a second effective microseismic event is determined by a second engineering parameter. This is used to determine the changing characteristics of the microseismic event. Further, it is determined whether the second effective microseismic event meets a first preset condition. If the first preset condition is met, the second engineering parameter is determined as the actual adjusted engineering parameter, and construction is carried out using the second engineering parameter. If the condition is not met, a third engineering parameter can be re-determined. Therefore, dynamic real-time adjustment of engineering parameters can be achieved, thereby providing faster and more accurate guidance for construction and improving construction efficiency.

[0098] Example 1

[0099] Multiple microseismic monitoring wells were implemented in a shale oil block, with a designed well depth of 4500-6000 meters, a vertical depth of 3500-4200 meters, and a horizontal section to be fractured of 1500-1800 meters. The fracturing project was designed for 20-30 sections. Based on Figure 3 The steps shown are used to analyze and mine engineering data to guide the optimization of hydraulic fracturing engineering parameters.

[0100] Step 1: Identify the first effective microseismic event. Based on the monitored microseismic results, the first effective microseismic event is selected using b-value analysis or time-offset intersection analysis, eliminating the influence of natural fracture activity on the microseismic results. Figure 4 and Figure 5 As shown.

[0101] Figure 4 The diagram illustrates the determination of the first effective microseismic event using the b-value analysis method according to an embodiment of the present disclosure.

[0102] like Figure 4 As shown, the left figure is a schematic diagram of the frequency-magnitude distribution of natural cracks, with the horizontal axis representing magnitude M and the vertical axis representing the number of events N. Figure 4 As shown, the b-value in the natural fracture frequency-magnitude distribution map is close to 1. The right figure is a schematic diagram of the artificial fracture frequency-magnitude distribution, with the horizontal axis representing magnitude M and the vertical axis representing the number of events N. Figure 4 As shown, the b value in the artificial crack frequency-magnitude distribution map is close to 2.

[0103] Figure 5 The diagram illustrates the determination of the first effective microseismic event using the time-offset intersection analysis method according to an embodiment of the present disclosure.

[0104] like Figure 5 As shown, the horizontal axis represents time (min) and the vertical axis represents distance (m). The boxes inside the axes represent microseismic events caused by hydraulic fracturing, while the boxes outside the axes represent microseismic events caused by natural fractures.

[0105] Step 2: Based on the first effective microseismic event, determine its parameter information. By analyzing the occurrence time and spatial location of the first effective microseismic event, calculate parameters such as the number of occurrences, frequency, fracture network extension rate, and fracture network complexity. Figures 6-9 As shown.

[0106] Figure 6 The diagram illustrates the relationship between the flank sweep length and sweep depth of a first effective microseismic event according to an embodiment of the present disclosure.

[0107] like Figure 6As shown, the horizontal axis represents the sweep length of the two wings, and the vertical axis represents the sweep depth. Figure 6 It can reflect the spatial distribution of the first effective microseismic event during the hydraulic fracturing process.

[0108] Figure 7 A schematic diagram illustrating the relationship between the number of first effective microseismic events and the fracturing fluid volume according to an embodiment of the present disclosure is provided.

[0109] like Figure 7 As shown, the horizontal axis represents the fracturing fluid volume, and the vertical axis represents the number of microseismic events. (This is achieved through...) Figure 7 You can visually observe how the number of microseismic events changes as the liquid volume increases.

[0110] Figure 8 The diagram illustrates the relationship between the number of first effective microseismic events and fracturing time according to an embodiment of the present disclosure.

[0111] like Figure 8 As shown, the horizontal axis represents fracturing time (min), and the vertical axis represents the number of microseismic events. (The text repeats itself here.) Figure 8 It allows for a direct view of how the number of microseismic events changes over time.

[0112] Figure 9 A schematic diagram illustrating the relationship between the crack propagation velocity of a first effective microseismic event according to an embodiment of the present disclosure is provided.

[0113] like Figure 9 As shown, the horizontal axis represents velocity, and the vertical axis represents the fracturing stage number. (Through...) Figure 9 It allows for a direct comparison of the differences in fracture propagation rates between different fracturing sections.

[0114] Step 3: Based on the parameter information of the first effective microseismic event and the first engineering parameters, determine the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameters. Read the first engineering parameters such as displacement, pressure, fluid volume, sand ratio, and viscosity during the current fracturing operation, and draw corresponding charts for quantitative analysis to find the relationship between the two. For example... Figures 10-20 As shown. It is understandable that... Figures 10-20 Only some of the relationships between the first engineering parameters and the parameter information of the first effective microseismic event are listed. According to the processing method of the embodiments of this disclosure, other corresponding charts can also be determined to guide the optimization of hydraulic fracturing engineering parameters, which are not limited here.

[0115] Figure 10 The diagram illustrates the relationship between the fracturing fluid volume in each fracturing segment and the length of the first effective microseismic event according to an embodiment of the present disclosure.

[0116] like Figure 10As shown, the horizontal axis represents the cumulative hydraulic pressure (m). 3 The vertical axis represents the seam length (m). (The text abruptly ends here.) Figure 10 This allows for a direct view of how the number of effective microseismic events changes with the fracturing fluid volume in each segment, and a clear comparison of the differences between segments. This information can then be used to select the appropriate fracturing fluid volume.

[0117] Figure 11 The diagram illustrates the relationship between the number of first effective microseismic events, event energy, and fracture length at different fluid volume stages of hydraulic fracturing according to embodiments of the present disclosure.

[0118] like Figure 11 As shown, the horizontal axis represents liquid volume, and the vertical axis represents the number of first effective microseismic events, the energy of the first effective microseismic event, and the crack length of the first effective microseismic event. Figure 11 It allows for a direct view of the changes in the first effective microseismic event during every 500 cubic meters of liquid volume. Based on Figure 11 The relationship shown can be used to select the appropriate fracturing fluid volume.

[0119] Figure 12 The schematic diagram illustrates the relationship between the two wing sweep lengths during different temporary plugging stages of hydraulic fracturing according to embodiments of the present disclosure.

[0120] like Figure 12 As shown, the horizontal axis represents the sweep length of both wings, and the vertical axis represents each temporary blockage stage. (Through...) Figure 12 It allows for a direct view of the changes in the first effective microseismic event during each temporary blocking phase, thus enabling a comparison of the effectiveness of each temporary blocking.

[0121] Figure 13 The diagram illustrates the relationship between displacement and pressure corresponding to a first effective microseismic event according to an embodiment of the present disclosure.

[0122] pass Figure 13 It allows for a direct view of the pressure and displacement conditions at the time of the first effective microseismic event, which can guide displacement adjustment and optimization.

[0123] Figure 14 The diagram illustrates the relationship between the number of perforation clusters in each section of a hydraulically fractured well and the number of first effective microseismic events according to an embodiment of the present disclosure.

[0124] like Figure 14 As shown, the horizontal axis represents the number of perforation clusters in each section of the hydraulically fractured well, and the vertical axis represents the number of first effective microseismic events. Through Figure 14 The relationship between the number of perforation clusters and the number of microseismic events can be viewed intuitively, which can guide the optimization design of the number of perforation clusters.

[0125] Figure 15The diagram illustrates the relationship between the fluid volume in each section of a hydraulically fractured well and the swept volume of a first effective microseismic event according to an embodiment of the present disclosure.

[0126] like Figure 15 As shown, the horizontal axis represents the fracturing fluid volume (m³). 3 ), with the vertical axis representing the swept volume (10 4 m 3 ).pass Figure 15 It allows for a direct view of the relationship between fracturing fluid volume and the volume of the first effective microseismic wave, which can guide the optimization design of fracturing fluid volume.

[0127] Figure 16 The diagram illustrates the relationship between the fluid volume in each section of a hydraulically fractured well and the swept fracture length of a first effective microseismic event according to an embodiment of the present disclosure.

[0128] like Figure 16 As shown, the horizontal axis represents the fracturing fluid volume (m³). 3 The vertical axis represents the ripple length (m). (The text abruptly ends here.) Figure 16 It allows for a direct view of the relationship between fracturing fluid volume, the first effective microseismic wave, and the fracture length, thereby guiding the optimization design of fracturing fluid volume.

[0129] Figure 17 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the number of first effective microseismic events according to an embodiment of the present disclosure.

[0130] like Figure 17 As shown, the horizontal axis represents the average displacement (m³ / s). 3 / min), with the vertical axis representing the number of events (individual events). Figure 17 It allows for a direct view of the relationship between the average discharge rate of each section of a hydraulically fractured well and the number of first effective microseismic events, which can guide the adjustment of relevant engineering parameters.

[0131] Figure 18 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the swept volume of a first effective microseismic event according to an embodiment of the present disclosure.

[0132] like Figure 18 As shown, the horizontal axis represents the average displacement (m³ / s). 3 / min), with the vertical axis representing the swept volume (10 4 m 3 ).pass Figure 18 It allows for a direct view of the relationship between the average discharge rate of each section of a hydraulically fractured well and the swept volume of the first effective microseismic event, thereby guiding the adjustment of relevant engineering parameters.

[0133] Figure 19The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture length of a first effective microseismic event according to an embodiment of the present disclosure.

[0134] like Figure 19 As shown, the horizontal axis represents the average displacement (m³ / s). 3 / min), with the vertical axis representing the seam length (m). Through Figure 19 It allows for a direct view of the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture length of the first effective microseismic event, thereby guiding the adjustment of relevant engineering parameters.

[0135] Figure 20 The diagram illustrates the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture width of a first effective microseismic event, according to an embodiment of the present disclosure.

[0136] like Figure 20 As shown, the horizontal axis represents the average displacement (m³ / s). 3 / min), with the vertical axis representing the seam width (m). Through Figure 20 It allows for a direct view of the relationship between the average discharge rate of each section of a hydraulically fractured well and the fracture width of the first effective microseismic event, thereby guiding the adjustment of relevant engineering parameters.

[0137] Step 4: Based on the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameters, determine the second engineering parameters. According to the corresponding intersection chart, visually observe the changes in the first effective microseismic event caused by the first engineering parameters such as fracturing fluid volume, displacement, and fracturing, and make corresponding adjustments based on these changes to determine the second engineering parameters.

[0138] Step 5: Verify whether the second engineering parameters meet the first preset conditions. Verify the rationality of the second engineering parameters by calculating the variation characteristics of the second effective microseismic event. If unreasonable, the parameter optimization adjustment has not achieved the expected results, and Step 4 needs to be repeated; if all parameters are reasonable, the parameter optimization adjustment process is complete, and the final determined engineering parameters can then guide on-site construction.

[0139] Figure 21 A block diagram of a computer device according to an embodiment of the present disclosure is shown schematically.

[0140] like Figure 21 As shown, the computer device 2100 of this embodiment includes a memory 2101, a processor 2102, and a computer program 2103 stored in the memory. The processor 2102 executes the computer program 2103 to implement the steps of the processing method.

[0141] Figure 22 A block diagram illustrating a computer-readable storage medium according to an embodiment of the present disclosure is shown.

[0142] like Figure 22 As shown, a computer-readable storage medium 2200 of this disclosure embodiment is used to store a computer program 2201, which implements the steps of a processing method when executed by a processor.

[0143] Figure 23 A block diagram illustrating a computer program product according to an embodiment of the present disclosure is shown schematically.

[0144] like Figure 23 As shown, a computer program product 2300 according to an embodiment of the present disclosure includes a computer program 2301, which implements the steps of a processing method when executed by a processor.

[0145] The above description, with reference to the accompanying drawings, describes a processing method, medium, and computer program product based on microseismic monitoring according to embodiments of the present disclosure. The method involves screening first effective microseismic events and determining their parameter information. This information is then used to determine an intersection chart representing the parameter information of the first effective microseismic events and first engineering parameters. Based on this intersection chart, second engineering parameters can be determined. If the second engineering parameters meet the requirements, they are used to guide the construction of the next stage of the project. If the second engineering parameters do not meet the requirements, the engineering parameters can be dynamically adjusted in real time to optimize the project. Therefore, on the one hand, this reduces the computational workload of on-site personnel and improves drawing efficiency; on the other hand, it helps engineering technicians make quick decisions based on changes in the intersection chart.

[0146] In the embodiments of this disclosure, the processor may include, but is not limited to, one or more processors or microprocessors. Each processor may be implemented as an Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor, or other electronic components, for executing the methods in the above embodiments.

[0147] In embodiments of this disclosure, the computer-readable storage medium may be implemented by any type of volatile or non-volatile storage device or a combination thereof. The computer-readable storage medium may include, but is not limited to, random access memory (RAM), read-only memory (ROM), flash memory, EPROM memory, EEPROM memory, registers, and computer storage media (e.g., hard disk, floppy disk, solid-state drive, removable disk, CD-ROM, DVD-ROM, Blu-ray disc, etc.).

[0148] Computer-readable storage media may also store at least one computer-executable program / instruction, such as computer-readable instructions. Computer-readable storage media include, but are not limited to, volatile memory and / or non-volatile memory. Volatile memory may include, for example, random access memory (RAM) and / or cache memory. Computer-readable storage media may include, for example, read-only memory (ROM), hard disk, flash memory, etc. For example, a non-transitory computer-readable storage medium may be connected to a computing device such as a computer, and then, when the computing device executes the computer-readable instructions stored on the computer-readable storage medium, the various methods described above can be performed.

[0149] In addition, the computer device may include (but is not limited to) a data bus, an input / output (I / O) bus, a display, and input / output devices (e.g., keyboard, mouse, speakers, etc.).

[0150] The processor can communicate with external devices via the I / O bus through wired or wireless networks.

[0151] In one embodiment, the at least one computer-executable instruction may also be compiled into or comprise a software product / computer program product, wherein one or more computer-executable instructions are executed by a processor to perform the steps of the various functions and / or methods in the embodiments described herein.

[0152] In the embodiments provided in this disclosure, it should be understood that the disclosed apparatus and methods can also be implemented in other ways. The apparatus embodiments described above are merely illustrative; for example, the flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods, and computer program products according to various embodiments of this disclosure. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than those marked in the drawings. For example, two consecutive blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in a block diagram and / or flowchart, and combinations of blocks in block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or action, or using a combination of dedicated hardware and computer instructions.

[0153] It should be noted that, in this disclosure, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitation, an element limited by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0154] While the embodiments disclosed herein are as described above, the foregoing content is merely for the purpose of facilitating understanding of this disclosure and is not intended to limit this disclosure. Any person skilled in the art to which this disclosure pertains may make any modifications and changes in form and detail of the implementation without departing from the spirit and scope of this disclosure; however, the scope of patent protection of this disclosure shall still be determined by the scope defined in the appended claims.

Claims

1. A processing method based on microseismic monitoring, characterized in that, The method includes: Identify the first valid microseismic event; Based on the first effective microseismic event, determine the parameter information of the first effective microseismic event; and Based on the parameter information of the first effective microseismic event, the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter is determined.

2. The treatment method according to claim 1, characterized in that, The determination of the first effective microseismic event includes: The first effective microseismic event is determined based on b-value analysis and / or time-offset intersection analysis.

3. The treatment method of claim 1, wherein, The parameter information of the first effective microseismic event includes at least one or more of the following: the number of occurrences of the first effective microseismic event, frequency, seismic network extension speed, and seismic network complexity.

4. The treatment method according to any one of claims 1 to 3, characterized in that, The step of determining the correspondence between the parameter information of the first effective microseismic event and the first engineering parameter based on the parameter information of the first effective microseismic event includes: Based on the parameter information of the first effective microseismic event and the first engineering parameter, determine the intersection chart of the parameter information of the first effective microseismic event and the first engineering parameter; The first engineering parameter includes at least one or more of the following: displacement, pressure, liquid volume, sand ratio, and viscosity.

5. The treatment method according to claim 4, characterized in that, The method further includes: Based on the intersection map of the parameter information of the first effective microseismic event and the first engineering parameters, the second engineering parameters are determined; The second engineering parameter includes at least one or more of the following: displacement, pressure, liquid volume, sand ratio, viscosity, and temporary plugging timing.

6. The treatment method according to claim 5, characterized in that, The method further includes: Based on the second engineering parameters, the second effective microseismic event is determined; Determine whether the second effective microseismic event meets the first preset condition; and In response to the second effective microseismic event satisfying the first preset condition, the second engineering parameter is determined to be the actual adjusted engineering parameter.

7. The treatment method according to claim 6, characterized in that, The method further includes: In response to the second effective microseismic event not meeting the first preset condition, a third engineering parameter is determined; Based on the aforementioned third engineering parameters, the third effective microseismic event is determined; and Determine whether the third effective microseismic event meets the first preset condition.

8. A computer device comprising a memory, a processor, and a computer program stored on the memory, wherein the computer program comprises instructions that, when executed by the processor, cause the processor to perform the method of any one of claims 1-7. The processor executes the computer program to implement the steps of the processing method according to any one of claims 1 to 7.

9. A computer readable storage medium having stored thereon a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the processing method according to any one of claims 1 to 7.

10. A computer program product comprising a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the processing method according to any one of claims 1 to 7.

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