Method, device, equipment and storage medium for determining distribution parameters of reservoir

Abstract

The present application provides a reservoir distribution parameter method, device, equipment and storage medium, belonging to the field of oil and gas development technology. The device includes: determining multiple initial detection points in a work area to be determined, and determining multiple target initial detection points containing shale gas from the multiple initial detection points according to a first pulse signal; for each target initial detection point, determining a detection area centered on the target initial detection point, determining a target area containing shale gas in the detection area, and obtaining multiple target areas; for each target area, determining multiple first target detection points along the extension direction of the target area and on both sides of the target area, determining the first distribution parameters of the target reservoir at the location of the multiple first target detection points; and determining the second distribution parameters of the shale gas reservoir according to the first distribution parameters. Since the pulse signal is an acoustic wave signal, there is no need to perform preparatory work such as drilling the reservoir, so the efficiency of determining the distribution parameters of the reservoir is improved.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas development, and in particular to a method, device, equipment and storage medium for determining distribution parameters of a reservoir. Background Art

[0002] The shale gas in the shale gas reservoir is a natural gas resource that can be mined, and has the advantages of long mining life and long production cycle. Before developing the shale gas reservoir in the work area, in order to determine the appropriate mining location, it is necessary to determine the distribution area of ​​shale gas in the shale gas reservoir, that is, the distribution parameters of the shale gas reservoir.

[0003] In the related art, the distribution area of ​​shale gas in the shale gas reservoir is determined by taking a point pressure method. The method includes determining multiple test points included in the work area, drilling a hole from the test point to the shale gas layer for each test point, and determining whether there is shale gas in the shale gas reservoir where the test point is located based on whether there is gas pressure at the test point. After testing multiple test points one by one, the distribution area of ​​shale gas in the shale gas reservoir is obtained.

[0004] However, in the above-mentioned related technologies, since each test point needs to be punched, when there are many test points in the work area, it takes a long time to punch multiple test points, resulting in low efficiency in determining the distribution parameters through the above-mentioned related technologies. Summary of the invention

[0005] The embodiment of the present application provides a method, device, computer equipment and storage medium for determining the distribution parameters of a reservoir, which can improve the efficiency of determining the distribution parameters. The technical solution is as follows:

[0006] In one aspect, the present application provides a method for determining distribution parameters of a reservoir, the method comprising:

[0007] Determine a plurality of initial detection points in the work area to be determined, and determine a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to a first pulse signal, wherein the first pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the initial detection point;

[0008] For each target initial detection point, determining a detection area centered on the target initial detection point, determining a target area containing shale gas in the detection area, and obtaining a plurality of target areas;

[0009] For each target area, a plurality of first target detection points are determined along the extension direction of the target area and on both sides of the target area, and a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points is determined;

[0010] The second distribution parameter of the shale gas reservoir is determined according to the first distribution parameter of the target reservoir at the locations of the multiple first target detection points.

[0011] In a possible implementation, determining a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to the first pulse signal includes:

[0012] For each initial detection point, a first reflection signal at the location of the initial detection point is obtained, where the first reflection signal is a reflection signal of the first pulse signal reflected by the shale gas reservoir;

[0013] Determining a plurality of propagation velocities corresponding to the first reflected signal in a plurality of rock layers included in the shale gas reservoir;

[0014] If the multiple propagation velocities include a target velocity corresponding to shale gas, the initial detection point is determined to be a target initial detection point containing shale gas.

[0015] In another possible implementation, determining the target area containing shale gas in the detection area includes:

[0016] Determine a plurality of detection points included in the detection area, and for each detection point, obtain a second reflection signal at the location of the detection point, wherein the second reflection signal is a reflection signal of the second pulse signal reflected by the shale gas reservoir, and the second pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the detection point;

[0017] determining a plurality of second target detection points containing shale gas from the plurality of detection points according to the second reflected signal;

[0018] According to the positions of the plurality of second target detection points, the outermost plurality of edge second target detection points are determined from the plurality of second target detection points, the plurality of edge second target detection points are connected, and the area within the connected closed loop is determined as the target area of ​​the detection area.

[0019] In another possible implementation, the first distribution parameter includes rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir;

[0020] The step of determining the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points comprises:

[0021] For each first target detection point, a third reflection signal at the location of the first target detection point is obtained, wherein the third reflection signal is a reflection signal of the third pulse signal reflected by the shale gas reservoir, and the third pulse signal is a pulse signal emitted by the ultrasonic detector at the location of the first target detection point;

[0022] determining a plurality of propagation speeds and a plurality of propagation time periods included in the third reflected signal;

[0023] Determine the rock formation types and rock formation thicknesses of multiple target rock formations in the reservoir according to the multiple propagation velocities and the multiple propagation time periods, and obtain first distribution parameters of the target reservoir at the locations of the multiple first target detection points;

[0024] Among them, one target rock layer corresponds to one propagation speed and one propagation time period.

[0025] In another possible implementation, determining the rock formation types and rock formation thicknesses of the multiple target rock formations in the reservoir according to the multiple propagation velocities and the multiple propagation time periods includes:

[0026] For each propagation velocity, determining the rock type of the target rock layer corresponding to the propagation velocity from the relationship between the rock layer type and the propagation velocity, and obtaining the rock layer types of the multiple target rock layers;

[0027] For each target rock layer, the rock layer thickness of the target rock layer is determined according to the product of the propagation velocity corresponding to the target rock layer and the propagation time period, so as to obtain the rock layer thicknesses of the multiple target rock layers.

[0028] In another possible implementation, before determining the rock formation types and rock formation thicknesses of the plurality of target rock formations in the reservoir according to the plurality of propagation velocities and the plurality of propagation time periods, the method further includes:

[0029] Determine a plurality of third target detection points above the target area, collect rock formation samples of the shale gas reservoir at the third target detection points, the rock formation samples include multiple types of rock formations;

[0030] For each type of rock formation, determining a propagation speed of the third pulse signal in the rock formation;

[0031] The rock formation type of the rock formation is associated with the propagation velocity to obtain a relationship between the rock formation type and the propagation velocity.

[0032] In another possible implementation, the first distribution parameter includes rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir;

[0033] The determining of the second distribution parameter of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points comprises:

[0034] Determine a fault point of the shale gas reservoir according to a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, wherein the fault point is located between two adjacent target rock formations;

[0035] According to the fault point, the fault planes, rock formation types and rock formation thicknesses of multiple target rock formations in the shale gas reservoir are determined, and the fault planes, rock formation types and rock formation thicknesses of the multiple target rock formations are determined as second distribution parameters of the shale gas reservoir.

[0036] In another possible implementation, determining the fault point of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points includes:

[0037] Determine a plurality of adjacent fourth target detection points and a fifth target detection point from the plurality of first target detection points according to a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, wherein the rock formation types of the plurality of target rock formations included in the target reservoir at the locations of the fourth target detection points are different from the rock formation types of the plurality of target rock formations included in the target reservoir at the locations of the fifth target detection points;

[0038] Acquire the first positions of the plurality of fourth target detection points and the second positions of the plurality of fifth target detection points;

[0039] The midpoint between the first position and the second position is determined to be the fault point of the shale gas reservoir.

[0040] In another possible implementation, the multiple target rock formations include a shale gas layer, and the second distribution parameter includes a quality parameter of the shale gas layer; the method further includes:

[0041] Determining a first fault plane at the top of the shale gas layer and a second fault plane at the bottom of the shale gas layer according to the fault points;

[0042] Determining a volume parameter of the shale gas layer according to the first fault plane and the second fault plane;

[0043] The density of the shale gas layer is obtained, and the product of the volume parameter and the density is determined as the mass parameter of the shale gas layer.

[0044] On the other hand, the present application provides a device for determining a distribution parameter of a reservoir, the device comprising:

[0045] A first determination module is used to determine a plurality of initial detection points in a work area to be determined, and to determine a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to a first pulse signal, wherein the first pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the initial detection point;

[0046] A second determination module is used to determine, for each target initial detection point, a detection area centered on the target initial detection point, determine a target area containing shale gas in the detection area, and obtain multiple target areas;

[0047] A third determination module is used to determine, for each target area, a plurality of first target detection points along the extension direction of the target area and on both sides of the target area, and determine first distribution parameters of the target reservoir at the locations of the plurality of first target detection points;

[0048] The fourth determination module is used to determine the second distribution parameter of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the multiple first target detection points.

[0049] In one possible implementation, the first determination module is used to obtain, for each initial detection point, a first reflection signal at the location of the initial detection point, where the first reflection signal is a reflection signal of the first pulse signal reflected by the shale gas reservoir; determine a plurality of propagation velocities corresponding to the first reflection signal in a plurality of rock formations included in the shale gas reservoir; and if the plurality of propagation velocities include a target velocity corresponding to shale gas, determine that the initial detection point is a target initial detection point containing shale gas.

[0050] In another possible implementation, the second determination module is used to determine multiple detection points included in the detection area, and for each detection point, obtain a second reflection signal at the location of the detection point, where the second reflection signal is a reflection signal of a second pulse signal reflected by the shale gas reservoir, and the second pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the detection point; based on the second reflection signal, determine multiple second target detection points containing shale gas from the multiple detection points; based on the positions of the multiple second target detection points, determine the outermost multiple edge second target detection points from the multiple second target detection points, connect the multiple edge second target detection points, and determine the area within the closed loop obtained by the connection as the target area of ​​the detection area.

[0051] In another possible implementation, the first distribution parameter includes rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir; and the third determination module includes:

[0052] A first acquisition unit is used to acquire, for each first target detection point, a third reflection signal at a location where the first target detection point is located, wherein the third reflection signal is a reflection signal of a third pulse signal reflected by the shale gas reservoir, and the third pulse signal is a pulse signal emitted by an ultrasonic detector at the location where the first target detection point is located;

[0053] A first determining unit, configured to determine a plurality of propagation speeds and a plurality of propagation time periods included in the third reflected signal;

[0054] A second determination unit is used to determine the rock formation types and rock formation thicknesses of the multiple target rock formations in the reservoir according to the multiple propagation velocities and the multiple propagation time periods, and obtain a first distribution parameter of the target reservoir at the location of the multiple first target detection points;

[0055] Among them, one target rock layer corresponds to one propagation speed and one propagation time period.

[0056] In another possible implementation, the second determination unit is used to determine, for each propagation velocity, the rock type of the target rock formation corresponding to the propagation velocity from the relationship between the rock formation type and the propagation velocity, and obtain the rock formation types of the multiple target rock formations; for each target rock formation, determine the rock formation thickness of the target rock formation according to the product of the propagation velocity corresponding to the target rock formation and the propagation time period, and obtain the rock formation thicknesses of the multiple target rock formations.

[0057] In another possible implementation, before determining the rock formation types and rock formation thicknesses of the plurality of target rock formations in the reservoir according to the plurality of propagation velocities and the plurality of propagation time periods, the device further includes:

[0058] A fifth determination module is used to determine a plurality of third target detection points above the target area, and collect rock formation samples of the shale gas reservoir at the third target detection points, wherein the rock formation samples include multiple types of rock formations;

[0059] a sixth determination module, configured to determine, for each type of rock formation, a propagation speed of the third pulse signal in the rock formation;

[0060] The association module is used to associate the rock formation type of the rock formation with the propagation velocity to obtain the relationship between the rock formation type and the propagation velocity.

[0061] In another possible implementation, the first distribution parameter includes rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir; the fourth determination module includes:

[0062] A third determining unit, configured to determine a fault point of the shale gas reservoir according to a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, wherein the fault point is located between two adjacent target rock formations;

[0063] The fourth determination unit is used to determine the fault plane, rock formation type and rock formation thickness of multiple target rock formations in the shale gas reservoir according to the fault point, and determine the fault plane, rock formation type and rock formation thickness of the multiple target rock formations as the second distribution parameters of the shale gas reservoir.

[0064] In another possible implementation, the third determination unit is used to determine a plurality of adjacent fourth target detection points and a fifth target detection point from the plurality of first target detection points according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, the formation types of the plurality of target rock formations included in the target reservoir at the locations of the fourth target detection points being different from the formation types of the plurality of target rock formations included in the target reservoir at the locations of the fifth target detection points; obtain the first positions of the plurality of fourth target detection points and the second positions of the plurality of fifth target detection points; and determine the midpoint of the first positions and the second positions as the fault point of the shale gas reservoir.

[0065] In another possible implementation, the multiple target rock formations include a shale gas layer, and the second distribution parameter includes a quality parameter of the shale gas layer; the device further includes:

[0066] A seventh determination module, configured to determine a first fault plane at the top of the shale gas layer and a second fault plane at the bottom of the shale gas layer according to the fault point;

[0067] an eighth determination module, configured to determine a volume parameter of the shale gas layer according to the first fault plane and the second fault plane;

[0068] The ninth determination module is used to obtain the density of the shale gas layer and determine the product of the volume parameter and the density as the quality parameter of the shale gas layer.

[0069] On the other hand, an embodiment of the present application provides a computer device, comprising: a processor and a memory, wherein the memory stores at least one program code, and the at least one program code is loaded and executed by the processor to implement the operations performed in the method for determining the distribution parameters of the reservoir described in any possible implementation method above.

[0070] On the other hand, an embodiment of the present application provides a computer-readable storage medium, in which at least one program code is stored. The at least one program code is loaded and executed by a processor to implement the operations performed in the method for determining the distribution parameters of the reservoir described in any possible implementation method mentioned above.

[0071] The beneficial effects of the technical solution provided by the embodiments of the present application include at least:

[0072] An embodiment of the present application provides a method for determining the distribution parameters of a reservoir. A plurality of target initial detection points containing shale gas are first determined from a plurality of initial detection points through a pulse signal, and then the area containing shale gas is directly detected. The distribution parameters of the reservoir in the area containing shale gas are used to determine the distribution parameters of the reservoir. The pulse signal is an acoustic wave signal, which can be directly propagated in the reservoir. In this way, there is no need to perform preparatory work such as drilling the reservoir, thereby improving the efficiency of determining the distribution parameters of the reservoir. BRIEF DESCRIPTION OF THE DRAWINGS

[0073] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0074] Figure 1 is a flow chart of a method for determining distribution parameters of a reservoir according to an exemplary embodiment;

[0075] Figure 2 is a block diagram of a device for determining distribution parameters of a reservoir according to an exemplary embodiment;

[0076] Figure 3 is a block diagram of a device for determining distribution parameters of a reservoir according to an exemplary embodiment;

[0077] Figure 4 It is a structural block diagram of a computer device provided according to an embodiment of the present application. DETAILED DESCRIPTION

[0078] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below with reference to the accompanying drawings.

[0079] Figure 1 FIG. 1 is a flow chart of a method for determining a distribution parameter of a reservoir according to an exemplary embodiment. Figure 1 , the method comprising:

[0080] 101. The computer device determines a plurality of initial detection points in a work area to be determined, and determines a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to the first pulse signal.

[0081] The first pulse signal is a pulse signal emitted by the ultrasonic detector at the location of the initial detection point. The emission period of the first pulse signal can be any value between 50 times / min and 100 times / min, for example, 50 times / min, 60 times / min, 70 times / min, etc. The frequency of the first pulse signal can be any value between 20KHz and 50KHz, for example, 20KHz, 30KHz, 40KHz, etc. In the embodiment of the present application, the frequency and emission period of the first pulse signal are not specifically limited and can be set and modified as needed.

[0082] In a possible implementation, the computer device determines multiple initial detection points by a five-point sampling method. Accordingly, the step of the computer device determining multiple initial detection points in the work area to be determined is: the computer device determines that the shape of the work area to be determined is a rectangle, and determines multiple initial detection points from the center position and four vertex positions of the rectangular work area.

[0083] In another possible implementation, the computer device may also determine multiple initial detection points by an equidistant sampling method. Accordingly, the step of the computer device determining multiple initial detection points in the work area to be determined is: the computer device determines the distance between any two adjacent initial detection points, and determines multiple initial detection points in the work area according to the distance.

[0084] The distance between any two adjacent initial detection points may be any value between 50m and 500m, for example, 50m, 100m, 150m, etc. In the embodiment of the present application, the value of the distance is not specifically limited and can be set and modified as needed.

[0085] In a possible implementation, the propagation speed of the first pulse signal in different media is different, and the computer device can determine the target initial detection point containing shale gas according to the propagation speed of the first pulse signal. Accordingly, the steps for the computer device to determine multiple target initial detection points containing shale gas from multiple initial detection points according to the first pulse signal are as follows: for each initial detection point, the computer device obtains the first reflection signal at the location of the initial detection point, the first reflection signal is the reflection signal of the first pulse signal reflected by the shale gas reservoir; determines the multiple propagation speeds corresponding to the first reflection signal in the multiple rock layers included in the shale gas reservoir; if the multiple propagation speeds include the target speed corresponding to shale gas, the initial detection point is determined to be the target initial detection point containing shale gas.

[0086] Wherein, the target speed can be a specific value or a range of values. In a possible implementation, the target speed is a range of values, which is greater than the first preset speed and less than the second preset speed. Wherein, the first preset speed can be any value between 300m / s and 340m / s, for example, 300m / s, 310m / s, 320m / s, etc.; the second preset speed can be any value between 350m / s and 500m / s, for example, 350m / s, 400m / s, 450m / s, etc.; in the embodiment of the present application, the values ​​of the first preset speed and the second preset speed are not specifically limited, and can be set and modified as needed.

[0087] In a possible implementation, the target speed corresponding to shale gas is the propagation speed of the first pulse signal in the shale gas, and the target speed of the first pulse signal propagating in the shale gas is stored in the computer device. Accordingly, the step of the computer device determining the target speed corresponding to shale gas included in the multiple propagation speeds is: the computer device obtains the stored target speed, compares the target speed with the multiple propagation speeds in sequence, and if there is a propagation speed that is the same as the target speed, then determines the target speed corresponding to shale gas included in the multiple propagation speeds.

[0088] 102. The computer device determines, for each target initial detection point, a detection area centered on the target initial detection point, determines a target area containing shale gas in the detection area, and obtains a plurality of target areas.

[0089] In this step, the detection area centered on the initial detection point can be a circle centered on the initial detection point, or a square, rectangle, etc. centered on the initial detection point; in the embodiment of the present application, the shape and area of ​​the detection area are not specifically limited and can be set and modified as needed.

[0090] In one possible implementation, the step of a computer device determining a target area containing shale gas in a detection area is as follows: the computer device determines a plurality of detection points included in the detection area, and for each detection point, obtains a second reflection signal at the location of the detection point, where the second reflection signal is a reflection signal of a second pulse signal reflected by a shale gas reservoir, and the second pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the detection point; based on the second reflection signal, determines a plurality of second target detection points containing shale gas from the plurality of detection points; and determines a target area containing shale gas in the detection area based on the positions of the plurality of second target detection points.

[0091] Optionally, multiple detection points may be equally spaced within the detection area. The distance between any two adjacent detection points may be any value between 50m and 500m, for example, 50m, 100m, 150m, etc. In the embodiment of the present application, the value of the distance is not specifically limited and may be set and modified as needed.

[0092] The second pulse signal is an ultrasonic pulse signal emitted by an ultrasonic detector, and the frequency and emission period of the second pulse signal may be the same as the frequency and emission period of the first pulse signal.

[0093] In one possible implementation, the steps for a computer device to determine a target area containing shale gas in a detection area based on the positions of multiple second target detection points are as follows: the computer device determines multiple outermost edge second target detection points from the multiple second target detection points based on the positions of the multiple second target detection points; the multiple edge second target detection points are connected, and the area within the closed loop obtained by the connection is determined as the target area of ​​the detection area.

[0094] In another possible implementation, the target area may also be a line. Accordingly, the step of determining the target area containing shale gas in the detection area according to the positions of the plurality of second target detection points by the computer device is as follows: the computer device determines a plurality of second target detection points closest to the center line from the plurality of second target detection points according to the positions of the plurality of second target detection points, connects the plurality of second target detection points closest to the center line to obtain a target line; and determines the target line as the target area of ​​the detection area.

[0095] 103. For each target area, the computer device determines a plurality of first target detection points along an extension direction of the target area and on both sides of the target area, and determines first distribution parameters of the target reservoir at locations of the plurality of first target detection points.

[0096] In a possible implementation, the computer device determines, for each target area, a center line of the target area, and determines a plurality of first target detection points along an extension direction of the center line and on both sides of the center line. Optionally, the farthest first target detection point along the extension direction of the center line is on an edge of the target work area, and the farthest first target detection points along both sides of the center line are on an edge of the target work area.

[0097] Optionally, multiple first target detection points may be equally spaced in the target work area, and the distance between any two adjacent first target detection points may be any value between 300m and 400m, for example, 300m, 350m, 400m, etc. In the embodiment of the present application, the value of the distance is not specifically limited and can be set and modified as needed.

[0098] In a possible implementation, the first distribution parameter includes the rock formation type and rock formation thickness of multiple target rock formations included in the shale gas reservoir. Accordingly, the step of the computer device determining the first distribution parameter of the target reservoir where the multiple first target detection points are located is as follows: for each first target detection point, the computer device obtains the third reflection signal at the location of the first target detection point, the third reflection signal is the reflection signal of the third pulse signal reflected by the shale gas reservoir, and the third pulse signal is the pulse signal emitted by the ultrasonic detector at the location of the first target detection point; determines the multiple propagation speeds and multiple propagation time periods included in the third reflection signal; determines the rock formation type and rock formation thickness of the multiple target rock formations in the reservoir according to the multiple propagation speeds and multiple propagation time periods, and obtains the first distribution parameter of the target reservoir where the multiple first target detection points are located; wherein one target rock formation corresponds to one propagation speed and one propagation time period.

[0099] Optionally, the third pulse signal is an ultrasonic signal, and the reservoir includes multiple target rock layers, and different target rock layers have different corresponding densities. The ultrasonic signal has different propagation speeds in different target rock layers, wherein one propagation speed corresponds to one propagation time period. Optionally, the first pulse signal, the second pulse signal, and the third pulse signal are the same pulse signal.

[0100] In a possible implementation, the relationship between the rock formation type and the propagation speed is stored in the computer device. Accordingly, the step of determining the rock formation type and rock formation thickness of multiple target rock formations in the reservoir according to multiple propagation speeds and multiple propagation time periods is as follows: for each propagation speed, the computer device determines the rock type of the target rock formation corresponding to the propagation speed from the relationship between the rock formation type and the propagation speed, and obtains the rock formation types of multiple target rock formations; for each target rock formation, the computer device determines the rock formation thickness of the target rock formation according to the propagation speed and propagation time period corresponding to the target rock formation, and obtains the rock formation thickness of multiple target rock formations.

[0101] Optionally, the computer device determines, based on the propagation velocity and the propagation time period corresponding to the target rock formation, that the product of the propagation velocity and the propagation time period is the rock formation thickness of the target rock formation.

[0102] In a possible implementation, the computer device determines the rock thickness of the target rock layer according to the propagation speed and propagation time period corresponding to the target rock layer by using the following formula 1:

[0103] Formula 1: W = V * T

[0104] Wherein, W represents the rock layer thickness of the target rock layer, V represents the propagation velocity corresponding to the target rock layer, and T represents the propagation time period corresponding to the target rock layer.

[0105] In a possible implementation, the steps of storing the relationship between the rock formation type and the propagation speed in the computer device are as follows: the computer device determines a plurality of third target detection points above the target area, collects rock formation samples of the shale gas reservoir at the third target detection points, and the rock formation samples include a plurality of types of rock formations; for each type of rock formation, determines the propagation speed of the pulse signal in the rock formation; associates the rock formation type of the rock formation with the propagation speed to obtain the relationship between the rock formation type and the propagation speed; and stores the relationship between the rock formation type and the propagation speed. Optionally, the pulse signal and the third pulse signal are the same signal.

[0106] Optionally, multiple third target detection points may be equally spaced in the target area, and the distance between any two adjacent third target detection points may be any value between 500m and 800m, for example, 500m, 600m, 700m, etc. In the embodiment of the present application, the value of the distance is not specifically limited and can be set and modified as needed.

[0107] 104. The computer device determines the second distribution parameter of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points.

[0108] In a possible implementation, this step is: the computer device determines the fault point of the shale gas reservoir based on the first distribution parameters of the target reservoir at the locations of multiple first target detection points, and the fault point is located between two adjacent target rock formations; based on the fault point, the fault plane, rock formation type and rock formation thickness of multiple target rock formations in the shale gas reservoir are determined, and the fault plane, rock formation type and rock formation thickness of the multiple target rock formations are determined as the second distribution parameters of the shale gas reservoir.

[0109] Among them, the step of the computer device determining the fault point of the shale gas reservoir according to the first distribution parameters of the target reservoir at the locations of multiple first target detection points is as follows: the computer device determines multiple adjacent fourth target detection points and fifth target detection points from the multiple first target detection points according to the first distribution parameters of the target reservoir at the locations of multiple first target detection points, and the rock formation types of the multiple target rock formations included in the target reservoir at the locations of the fourth target detection points are different from the rock formation types of the multiple target rock formations included in the target reservoir at the locations of the fifth target detection points; obtain the first positions of the multiple fourth target detection points and the second positions of the multiple fifth target detection points; and determine that the midpoint between the first position and the second position is the fault point of the shale gas reservoir.

[0110] In another possible implementation, the multiple target rock formations include a shale gas layer, and the second distribution parameter includes a quality parameter of the shale gas layer. Accordingly, the steps of determining the second distribution parameter of the shale gas reservoir by the computer device are: the computer device determines a first fault plane at the top of the shale gas layer and a second fault plane at the bottom of the shale gas layer according to the fault point; determines a volume parameter of the shale gas layer according to the first fault plane and the second fault plane; determines the density of the shale gas layer, and determines that the product of the volume parameter and the density is the quality parameter of the shale gas layer.

[0111] Optionally, the quality parameter of the shale gas layer can be represented by the letter M, the volume parameter can be represented by the letter S, the density of the shale gas layer can be represented by the letter ρ, and the quality parameter of the shale gas layer can be represented by the formula M=ρ*S.

[0112] In a possible implementation, the density of the shale gas layer is positively correlated with the propagation speed of the pulse signal in the shale gas layer, and the corresponding relationship between the density of the shale gas layer and the propagation speed is stored in the computer. Accordingly, the step of determining the density of the shale gas layer by the computer device is as follows: the computer device determines the propagation speed of the pulse signal in the shale gas layer, and according to the propagation speed, determines the density of the shale gas layer corresponding to the propagation speed from the stored corresponding relationship between the density of the shale gas layer and the propagation speed.

[0113] The correspondence between the density of the shale gas layer and the propagation speed may be a correspondence list, as shown in Table 1 below.

[0114] Table 1 Density corresponding to the propagation speed of conventional sound waves in gas

[0115] Speed ​​(m / s) Density of shale gas layer (Kg / m3) 340 0.7174 350 1.2000 400 3.9852 480 4.6873 500 4.9677

[0116] In another possible implementation, the pulse signal is an ultrasonic signal, and the propagation speed of the ultrasonic signal in the gas is related to the density of the gas. Accordingly, the steps of determining the density of the shale gas layer by the computer device are: the computer device determines the density of the air, the propagation speed of the ultrasonic signal in the air, and the propagation speed of the ultrasonic signal in the shale gas layer; according to the density of the air, the propagation speed of the ultrasonic signal in the air, and the propagation speed of the ultrasonic signal in the shale gas layer, the density of the shale gas layer is determined by the following formula 2;

[0117] Formula 2: ρ2=ρ1V2 / V1

[0118] Among them, ρ2 represents the density of the shale gas layer, ρ1 represents the density of the air, V1 represents the propagation speed of the ultrasonic signal in the air, and V2 represents the propagation speed of the ultrasonic signal in the shale gas layer.

[0119] An embodiment of the present application provides a method for determining the distribution parameters of a reservoir. A plurality of target initial detection points containing shale gas are first determined from a plurality of initial detection points through a pulse signal, and then the area containing shale gas is directly detected. The distribution parameters of the reservoir in the area containing shale gas are used to determine the distribution parameters of the reservoir. The pulse signal is an acoustic wave signal, which can be directly propagated in the reservoir. In this way, there is no need to perform preparatory work such as drilling the reservoir, thereby improving the efficiency of determining the distribution parameters of the reservoir.

[0120] Figure 2 is a block diagram of a device for determining a distribution parameter of a reservoir according to an exemplary embodiment. Figure 2 , the device comprises:

[0121] The first determination module 201 is used to determine a plurality of initial detection points in the work area to be determined, and determine a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to a first pulse signal, wherein the first pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the initial detection point;

[0122] The second determination module 202 is used to determine, for each target initial detection point, a detection area centered on the target initial detection point, determine a target area containing shale gas in the detection area, and obtain multiple target areas;

[0123] The third determination module 203 is used to determine, for each target area, a plurality of first target detection points along the extension direction of the target area and on both sides of the target area, and determine first distribution parameters of the target reservoir at the locations of the plurality of first target detection points;

[0124] The fourth determination module 204 is used to determine the second distribution parameter of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points.

[0125] In one possible implementation, the first determination module 201 is used to obtain, for each initial detection point, a first reflection signal at the location of the initial detection point, where the first reflection signal is a reflection signal of the first pulse signal reflected by the shale gas reservoir; determine multiple propagation velocities corresponding to the first reflection signal in multiple rock layers included in the shale gas reservoir; if the multiple propagation velocities include a target velocity corresponding to shale gas, determine that the initial detection point is a target initial detection point containing shale gas.

[0126] In another possible implementation, the second determination module 202 is used to determine multiple detection points included in the detection area, and for each detection point, obtain a second reflection signal at the location of the detection point, where the second reflection signal is a reflection signal of the second pulse signal reflected by the shale gas reservoir, and the second pulse signal is a pulse signal emitted by the ultrasonic detector at the location of the detection point; based on the second reflection signal, determine multiple second target detection points containing shale gas from the multiple detection points; based on the positions of the multiple second target detection points, determine the outermost multiple edge second target detection points from the multiple second target detection points, connect the multiple edge second target detection points, and determine the area within the closed loop obtained by the connection as the target area of ​​the detection area.

[0127] In another possible implementation, the first distribution parameter includes the rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir; see Figure 3 , the third determination module 203 includes:

[0128] The first acquisition unit 2031 is used to acquire, for each first target detection point, a third reflection signal at the location of the first target detection point, where the third reflection signal is a reflection signal of the third pulse signal reflected by the shale gas reservoir, and the third pulse signal is a pulse signal emitted by the ultrasonic detector at the location of the first target detection point;

[0129] A first determining unit 2032 is used to determine a plurality of propagation speeds and a plurality of propagation time periods included in the third reflected signal;

[0130] The second determination unit 2033 is used to determine the rock formation types and rock formation thicknesses of multiple target rock formations in the reservoir according to the multiple propagation speeds and the multiple propagation time periods, and obtain the first distribution parameters of the target reservoirs at the locations of the multiple first target detection points;

[0131] Among them, one target rock layer corresponds to one propagation speed and one propagation time period.

[0132] In another possible implementation, the second determination unit 2032 is used to determine, for each propagation velocity, the rock type of the target rock formation corresponding to the propagation velocity from the relationship between the rock formation type and the propagation velocity, and obtain the rock formation types of multiple target rock formations; for each target rock formation, determine the rock formation thickness of the target rock formation according to the product of the propagation velocity corresponding to the target rock formation and the propagation time period, and obtain the rock formation thicknesses of multiple target rock formations.

[0133] In another possible implementation, before determining the rock formation types and rock formation thicknesses of multiple target rock formations in the reservoir according to multiple propagation speeds and multiple propagation time periods, continue to refer to Figure 3 , the device further comprises:

[0134] A fifth determination module 205 is used to determine a plurality of third target detection points above the target area, and collect rock formation samples of the shale gas reservoir at the third target detection points, wherein the rock formation samples include multiple types of rock formations;

[0135] A sixth determination module 206, for determining a propagation speed of the third pulse signal in the rock formation for each type of rock formation;

[0136] The association module 207 is used to associate the rock formation type of the rock formation with the propagation velocity to obtain the relationship between the rock formation type and the propagation velocity.

[0137] In another possible implementation, the first distribution parameter includes the rock formation types and rock formation thicknesses of multiple target rock formations included in the shale gas reservoir; Figure 3 , the fourth determining module 204 includes:

[0138] The third determining unit 2041 is used to determine the fault point of the shale gas reservoir according to the first distribution parameter of the target reservoir at the location of the plurality of first target detection points, wherein the fault point is located between two adjacent target rock layers;

[0139] The fourth determination unit 2042 is used to determine the fault plane, rock formation type and rock formation thickness of multiple target rock formations in the shale gas reservoir according to the fault point, and determine the fault plane, rock formation type and rock formation thickness of multiple target rock formations as the second distribution parameters of the shale gas reservoir.

[0140] In another possible implementation, the third determination unit 2041 is used to determine a plurality of adjacent fourth target detection points and a fifth target detection point from the plurality of first target detection points based on the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, the formation types of the plurality of target rock formations included in the target reservoir at the locations of the fourth target detection points being different from the formation types of the plurality of target rock formations included in the target reservoir at the locations of the fifth target detection points; obtain the first positions of the plurality of fourth target detection points and the second positions of the plurality of fifth target detection points; and determine the midpoint of the first position and the second position as the fault point of the shale gas reservoir.

[0141] In another possible implementation, the multiple target rock formations include a shale gas layer, and the second distribution parameter includes a quality parameter of the shale gas layer; Figure 3 , the device further comprises:

[0142] A seventh determination module 208 is used to determine a first fault plane at the top of the shale gas layer and a second fault plane at the bottom of the shale gas layer according to the fault points;

[0143] An eighth determination module 209 is used to determine the volume parameter of the shale gas layer according to the first fault plane and the second fault plane;

[0144] The ninth determination module 210 is used to obtain the density of the shale gas layer and determine the product of the volume parameter and the density as the quality parameter of the shale gas layer.

[0145] An embodiment of the present application provides a device for determining the distribution parameters of a reservoir. A plurality of target initial detection points containing shale gas are first determined from a plurality of initial detection points through a pulse signal, and then the area containing shale gas is directly detected. The distribution parameters of the reservoir in the area containing shale gas are used to determine the distribution parameters of the reservoir. The pulse signal is an acoustic wave signal, which can be directly propagated in the reservoir. In this way, there is no need to perform preparatory work such as drilling the reservoir, thereby improving the efficiency of determining the distribution parameters of the reservoir.

[0146] Figure 4 The structure block diagram of a terminal 400 provided by an exemplary embodiment of the present invention is shown. The terminal 400 may be: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III), an MP4 (Moving Picture Experts Group Audio Layer IV), a laptop computer or a desktop computer. The terminal 400 may also be called a user device, a portable terminal, a laptop terminal, a desktop terminal or other names.

[0147] Typically, the terminal 400 includes a processor 401 and a memory 402 .

[0148] The processor 401 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 401 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). The processor 401 may also include a main processor and a coprocessor. The main processor is a processor for processing data in the awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in the standby state. In some embodiments, the processor 401 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 401 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0149] The memory 402 may include one or more computer-readable storage media, which may be non-transitory. The memory 402 may also include a high-speed random access memory, and a non-volatile memory, such as one or more disk storage devices, flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in the memory 402 is used to store at least one instruction, which is used to be executed by the processor 401 to implement the method for determining the distribution parameters of the reservoir provided in the method embodiment of the present application.

[0150] In some embodiments, the terminal 400 may further optionally include: a peripheral device interface 403 and at least one peripheral device. The processor 401, the memory 402 and the peripheral device interface 403 may be connected via a bus or a signal line. Each peripheral device may be connected to the peripheral device interface 403 via a bus, a signal line or a circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 404, a display screen 405, a camera 406, an audio circuit 407, a positioning component 408 and a power supply 409.

[0151] The peripheral device interface 403 may be used to connect at least one peripheral device related to I / O (Input / Output) to the processor 401 and the memory 402. In some embodiments, the processor 401, the memory 402, and the peripheral device interface 403 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 401, the memory 402, and the peripheral device interface 403 may be implemented on a separate chip or circuit board, which is not limited in this embodiment.

[0152] The radio frequency circuit 404 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 404 communicates with the communication network and other communication devices through electromagnetic signals. The radio frequency circuit 404 converts the electrical signal into an electromagnetic signal for transmission, or converts the received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 404 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, and the like. The radio frequency circuit 404 can communicate with other terminals through at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: a metropolitan area network, various generations of mobile communication networks (2G, 3G, 4G and 5G), a wireless local area network and / or a WiFi (Wireless Fidelity) network. In some embodiments, the radio frequency circuit 404 may also include circuits related to NFC (Near Field Communication), which is not limited in this application.

[0153] The display screen 405 is used to display the UI (User Interface). The UI may include graphics, text, icons, videos and any combination thereof. When the display screen 405 is a touch display screen, the display screen 405 also has the ability to collect touch signals on the surface or above the surface of the display screen 405. The touch signal can be input to the processor 401 as a control signal for processing. At this time, the display screen 405 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, the display screen 405 can be one, and the front panel of the terminal 400 is set; in other embodiments, the display screen 405 can be at least two, which are respectively set on different surfaces of the terminal 400 or are folded; in some other embodiments, the display screen 405 can be a flexible display screen, which is set on the curved surface or folded surface of the terminal 400. Even, the display screen 405 can also be set to a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 405 can be made of materials such as LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode, organic light-emitting diode).

[0154] The camera assembly 406 is used to capture images or videos. Optionally, the camera assembly 406 includes a front camera and a rear camera. Typically, the front camera is arranged on the front panel of the terminal, and the rear camera is arranged on the back of the terminal. In some embodiments, there are at least two rear cameras, which are any one of a main camera, a depth of field camera, a wide-angle camera, and a telephoto camera, so as to realize the fusion of the main camera and the depth of field camera to realize the background blur function, the fusion of the main camera and the wide-angle camera to realize the panoramic shooting and VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, the camera assembly 406 may also include a flash. The flash can be a monochrome temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cold light flash, which can be used for light compensation at different color temperatures.

[0155] The audio circuit 407 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, and convert the sound waves into electrical signals and input them into the processor 401 for processing, or input them into the radio frequency circuit 404 to achieve voice communication. For the purpose of stereo acquisition or noise reduction, there may be multiple microphones, which are respectively arranged at different parts of the terminal 400. The microphone may also be an array microphone or an omnidirectional acquisition microphone. The speaker is used to convert the electrical signal from the processor 401 or the radio frequency circuit 404 into sound waves. The speaker may be a traditional film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can not only convert the electrical signal into sound waves audible to humans, but also convert the electrical signal into sound waves inaudible to humans for purposes such as ranging. In some embodiments, the audio circuit 407 may also include a headphone jack.

[0156] Positioning component 408 is used to locate the current geographical location of terminal 400 to implement navigation or LBS (Location Based Service). Positioning component 408 can be a positioning component based on the US GPS (Global Positioning System), China's Beidou system, Russia's Grenas system or the European Union's Galileo system.

[0157] The power supply 409 is used to power various components in the terminal 400. The power supply 409 can be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 409 includes a rechargeable battery, the rechargeable battery can support wired charging or wireless charging. The rechargeable battery can also be used to support fast charging technology.

[0158] In some embodiments, the terminal 400 further includes one or more sensors 410 , including but not limited to: an acceleration sensor 411 , a gyroscope sensor 412 , a pressure sensor 413 , a fingerprint sensor 414 , an optical sensor 415 , and a proximity sensor 416 .

[0159] The acceleration sensor 411 can detect the magnitude of acceleration on the three coordinate axes of the coordinate system established by the terminal 400. For example, the acceleration sensor 411 can be used to detect the components of gravity acceleration on the three coordinate axes. The processor 401 can control the display screen 405 to display the user interface in a horizontal view or a vertical view according to the gravity acceleration signal collected by the acceleration sensor 411. The acceleration sensor 411 can also be used to collect game or user motion data.

[0160] The gyro sensor 412 can detect the body direction and rotation angle of the terminal 400, and the gyro sensor 412 can cooperate with the acceleration sensor 411 to collect the user's 3D actions on the terminal 400. The processor 401 can implement the following functions based on the data collected by the gyro sensor 412: motion sensing (such as changing the UI according to the user's tilt operation), image stabilization during shooting, game control, and inertial navigation.

[0161] The pressure sensor 413 can be set on the side frame of the terminal 400 and / or the lower layer of the display screen 405. When the pressure sensor 413 is set on the side frame of the terminal 400, it can detect the user's holding signal of the terminal 400, and the processor 401 performs left and right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 413. When the pressure sensor 413 is set on the lower layer of the display screen 405, the processor 401 controls the operability controls on the UI interface according to the user's pressure operation on the display screen 405. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

[0162] The fingerprint sensor 414 is used to collect the user's fingerprint, and the processor 401 identifies the user's identity based on the fingerprint collected by the fingerprint sensor 414, or the fingerprint sensor 414 identifies the user's identity based on the collected fingerprint. When the user's identity is identified as a trusted identity, the processor 401 authorizes the user to perform relevant sensitive operations, which include unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings. The fingerprint sensor 414 can be set on the front, back, or side of the terminal 400. When a physical button or a manufacturer logo is set on the terminal 400, the fingerprint sensor 414 can be integrated with the physical button or the manufacturer logo.

[0163] The optical sensor 415 is used to collect the ambient light intensity. In one embodiment, the processor 401 can control the display brightness of the display screen 405 according to the ambient light intensity collected by the optical sensor 415. Specifically, when the ambient light intensity is high, the display brightness of the display screen 405 is increased; when the ambient light intensity is low, the display brightness of the display screen 405 is decreased. In another embodiment, the processor 401 can also dynamically adjust the shooting parameters of the camera assembly 406 according to the ambient light intensity collected by the optical sensor 415.

[0164] The proximity sensor 416, also called a distance sensor, is usually disposed on the front panel of the terminal 400. The proximity sensor 416 is used to collect the distance between the user and the front of the terminal 400. In one embodiment, when the proximity sensor 416 detects that the distance between the user and the front of the terminal 400 is gradually decreasing, the processor 401 controls the display screen 405 to switch from the screen-on state to the screen-off state; when the proximity sensor 416 detects that the distance between the user and the front of the terminal 400 is gradually increasing, the processor 401 controls the display screen 405 to switch from the screen-off state to the screen-on state.

[0165] Those skilled in the art will understand that Figure 4 The structure shown in the figure does not constitute a limitation on the terminal 400, and the terminal 400 may include more or less components than those shown in the figure, or combine some components, or adopt a different component arrangement.

[0166] In an exemplary embodiment, a storage medium including a program code is also provided, such as a memory including the program code, and the program code can be executed by a processor of the device to complete the above method. Optionally, the storage medium can be a non-temporary computer-readable storage medium, for example, the non-temporary computer-readable storage medium can be a ROM (Read-Only Memory), a RAM (Random Access Memory), a CD-ROM (Compact Disc Read-Only Memory), a magnetic tape, a floppy disk, an optical data storage device, etc.

[0167] Those skilled in the art will readily appreciate other embodiments of the present disclosure after considering the specification and practicing the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of the present disclosure that follow the general principles of the present disclosure and include common knowledge or customary techniques in the art that are not disclosed in the present disclosure. The specification and examples are intended to be exemplary only, and the true scope and spirit of the present disclosure are indicated by the following claims.

[0168] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining distribution parameters of a shale gas reservoir, characterized in that: The method comprises: Determine a plurality of initial detection points in the work area to be determined, and determine a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to a first pulse signal, wherein the first pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the initial detection point; For each target initial detection point, determining a detection area centered on the target initial detection point, determining a target area containing shale gas in the detection area, and obtaining a plurality of target areas; For each target area, a plurality of first target detection points are determined along the extension direction of the target area and on both sides of the target area, and a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points is determined; Determining a second distribution parameter of the shale gas reservoir according to a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points; The first distribution parameter includes the rock formation type and rock formation thickness of multiple target rock formations included in the shale gas reservoir; the first distribution parameter of the target reservoir for determining the locations of the multiple first target detection points includes: For each first target detection point, a third reflection signal at the location of the first target detection point is obtained, wherein the third reflection signal is a reflection signal of a third pulse signal reflected by the shale gas reservoir, and the third pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the first target detection point; multiple propagation speeds and multiple propagation time periods included in the third reflection signal are determined; based on the multiple propagation speeds and multiple propagation time periods, the rock formation types and rock formation thicknesses of multiple target rock formations in the reservoir are determined, and the first distribution parameters of the target reservoirs at the locations of the multiple first target detection points are obtained; wherein one target rock formation corresponds to one propagation speed and one propagation time period; The method of determining the second distribution parameter of the shale gas reservoir based on the first distribution parameter of the target reservoir at the locations of the multiple first target detection points includes: determining the fault point of the shale gas reservoir based on the first distribution parameter of the target reservoir at the locations of the multiple first target detection points, wherein the fault point is located between two adjacent target rock formations; determining the fault plane, rock formation type and rock formation thickness of multiple target rock formations in the shale gas reservoir based on the fault point, and determining the fault plane, rock formation type and rock formation thickness of the multiple target rock formations as the second distribution parameter of the shale gas reservoir.

2. The method according to claim 1, characterized in that: The step of determining a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to the first pulse signal comprises: For each initial detection point, a first reflection signal at the location of the initial detection point is obtained, where the first reflection signal is a reflection signal of the first pulse signal reflected by the shale gas reservoir; Determining a plurality of propagation velocities corresponding to the first reflected signal in a plurality of rock layers included in the shale gas reservoir; If the multiple propagation velocities include a target velocity corresponding to shale gas, the initial detection point is determined to be a target initial detection point containing shale gas.

3. The method according to claim 1, characterized in that Determining the target area containing shale gas in the detection area includes: Determine a plurality of detection points included in the detection area, and for each detection point, obtain a second reflection signal at the location of the detection point, wherein the second reflection signal is a reflection signal of the second pulse signal reflected by the shale gas reservoir, and the second pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the detection point; determining a plurality of second target detection points containing shale gas from the plurality of detection points according to the second reflected signal; According to the positions of the plurality of second target detection points, the outermost plurality of edge second target detection points are determined from the plurality of second target detection points, the plurality of edge second target detection points are connected, and the area within the connected closed loop is determined as the target area of ​​the detection area.

4. The method according to claim 1, characterized in that: Determining the rock formation types and rock formation thicknesses of the plurality of target rock formations in the reservoir according to the plurality of propagation velocities and the plurality of propagation time periods comprises: For each propagation velocity, determining the rock type of the target rock layer corresponding to the propagation velocity from the relationship between the rock layer type and the propagation velocity, and obtaining the rock layer types of the multiple target rock layers; For each target rock layer, the rock layer thickness of the target rock layer is determined according to the product of the propagation velocity corresponding to the target rock layer and the propagation time period, so as to obtain the rock layer thicknesses of the multiple target rock layers.

5. The method according to claim 1, characterized in that Before determining the rock formation types and rock formation thicknesses of the plurality of target rock formations in the reservoir according to the plurality of propagation velocities and the plurality of propagation time periods, the method further comprises: Determine a plurality of third target detection points above the target area, collect rock formation samples of the shale gas reservoir at the third target detection points, the rock formation samples include multiple types of rock formations; For each type of rock formation, determining a propagation speed of the third pulse signal in the rock formation; The rock formation type of the rock formation is associated with the propagation velocity to obtain a relationship between the rock formation type and the propagation velocity.

6. The method according to claim 1, characterized in that The step of determining the fault point of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points comprises: Determine a plurality of adjacent fourth target detection points and a fifth target detection point from the plurality of first target detection points according to a first distribution parameter of the target reservoir at the locations of the plurality of first target detection points, wherein the rock formation types of the plurality of target rock formations included in the target reservoir at the locations of the fourth target detection points are different from the rock formation types of the plurality of target rock formations included in the target reservoir at the locations of the fifth target detection points; Acquire the first positions of the plurality of fourth target detection points and the second positions of the plurality of fifth target detection points; The midpoint between the first position and the second position is determined to be the fault point of the shale gas reservoir.

7. The method according to claim 1, characterized in that The multiple target rock formations include a shale gas layer, and the second distribution parameter includes a quality parameter of the shale gas layer; the method further includes: Determining a first fault plane at the top of the shale gas layer and a second fault plane at the bottom of the shale gas layer according to the fault points; Determining a volume parameter of the shale gas layer according to the first fault plane and the second fault plane; The density of the shale gas layer is obtained, and the product of the volume parameter and the density is determined as the mass parameter of the shale gas layer.

8. A device for determining distribution parameters of a shale gas reservoir, characterized in that: The device comprises: A first determination module is used to determine a plurality of initial detection points in a work area to be determined, and to determine a plurality of target initial detection points containing shale gas from the plurality of initial detection points according to a first pulse signal, wherein the first pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the initial detection point; A second determination module is used to determine, for each target initial detection point, a detection area centered on the target initial detection point, determine a target area containing shale gas in the detection area, and obtain multiple target areas; A third determination module is used to determine, for each target area, a plurality of first target detection points along the extension direction of the target area and on both sides of the target area, and determine first distribution parameters of the target reservoir at the locations of the plurality of first target detection points; A fourth determination module, configured to determine a second distribution parameter of the shale gas reservoir according to the first distribution parameter of the target reservoir at the locations of the plurality of first target detection points; The first distribution parameter includes the rock formation type and rock formation thickness of multiple target rock formations included in the shale gas reservoir; the third determination module is used to: For each first target detection point, a third reflection signal at the location of the first target detection point is obtained, wherein the third reflection signal is a reflection signal of a third pulse signal reflected by the shale gas reservoir, and the third pulse signal is a pulse signal emitted by an ultrasonic detector at the location of the first target detection point; multiple propagation speeds and multiple propagation time periods included in the third reflection signal are determined; based on the multiple propagation speeds and multiple propagation time periods, the rock formation types and rock formation thicknesses of multiple target rock formations in the reservoir are determined, and the first distribution parameters of the target reservoirs at the locations of the multiple first target detection points are obtained; wherein one target rock formation corresponds to one propagation speed and one propagation time period; The fourth determination module is used to: determine the fault point of the shale gas reservoir according to the first distribution parameter of the target reservoir at the location of the multiple first target detection points, and the fault point is located between two adjacent target rock formations; determine the fault plane, rock formation type and rock formation thickness of multiple target rock formations in the shale gas reservoir according to the fault point, and determine the fault plane, rock formation type and rock formation thickness of the multiple target rock formations as the second distribution parameters of the shale gas reservoir.

9. A computer device, characterized in that: The computer device comprises: A processor and a memory, wherein at least one program code is stored in the memory, and the at least one program code is loaded and executed by the processor to implement the operations performed in the method for determining the distribution parameters of the reservoir according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the operations performed in the method for determining the distribution parameters of a reservoir as claimed in any one of claims 1 to 7.

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