Method and device for determining shale gas reservoir quality parameter of type i and storage medium

Abstract

The application discloses a shale gas type I reservoir quality parameter determination method and device and a storage medium, and belongs to the technical field of shale gas exploration and development. The method processes data obtained from actual drilling, obtains a forward geology model, and obtains forward seismic profile data. A time difference value data set is obtained based on the data, wave impedance data is obtained by inverting the forward seismic profile data, and then a wave impedance ratio data set is obtained. A first formula is adjusted based on the time difference value data set and the wave impedance ratio data set, a second formula is obtained, and the quality parameters of each position in a to-be-studied area can be obtained based on the second formula and actual exploration seismic data of the to-be-studied area. The method processes data through model forward and post-stack sparse pulse inversion, and compared with pre-stack geostatistics inversion for processing data, the method solves the problems of large data processing amount, many parameters and complex process in the related art, and achieves the effect of reducing the data processing amount.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of shale gas exploration and development, and particularly relates to a shale gas type I reservoir quality parameter determination method and device and a storage medium. BACKGROUND

[0002] The quality parameter condition of a shale gas type I reservoir directly affects the yield of shale gas, and therefore the shale gas type I reservoir is identified. The identification method is directly related to whether the quality parameter of high-quality shale can be determined.

[0003] In a current shale gas type I reservoir quality parameter method, a pre-stack geostatistical inversion method is used to predict the quality parameter of high-quality shale by using parameters such as P-wave velocity, S-wave velocity and density.

[0004] However, the above identification method requires many parameters and has a complex calculation process, which increases the inversion calculation amount and the data processing amount. SUMMARY

[0005] Embodiments of the present application provide a shale gas type I reservoir quality parameter determination method and device and a storage medium. The technical solution is as follows:

[0006] According to a first aspect of the present application, a shale gas type I reservoir quality parameter determination method is provided, and the method comprises the following steps:

[0007] Obtaining well logging data, type I reservoir division data, geological layering data and actual exploration seismic data of real drilled wells in a to-be-studied area and a neighboring area;

[0008] According to the well logging data and the type I reservoir division data, a relationship among porosity, interval velocity and density in a reservoir of the to-be-studied area is obtained;

[0009] According to the relationship among the porosity, the interval velocity and the density, a plurality of wedge-shaped models of different type I reservoir continuous thicknesses and different porosities are established;

[0010] According to the geological layering data and acoustic logging velocity statistical data of the to-be-studied area, a geological background model is established;

[0011] The plurality of wedge-shaped models are embedded into the geological background model to obtain a forward geology model;

[0012] A forward seismic profile data is obtained by performing forward operation on the forward geology model by using a same dominant frequency Ricker wavelet of actual exploration seismic data corresponding to the to-be-studied area;

[0013] In the forward seismic profile data, a longitudinal time difference data set corresponding to two zero-phase layers adjacent to the strong reflection wave is calculated, and the time difference data set includes longitudinal time difference values corresponding to multiple plane positions in the two zero-phase layers;

[0014] Sparse pulse inversion is performed on the forward seismic profile data to obtain wave impedance profile data;

[0015] A wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data is determined;

[0016] The porosity of the forward geological model and the continuous thickness of the first type of reservoir are obtained;

[0017] The model real quality parameter Q is determined based on the porosity of the forward geological model and the continuous thickness of the first type of reservoir;

[0018] Based on the model real quality parameter and a first target formula, a first coefficient is adjusted so that the product of the time difference data set and the first coefficient is in the same value range as the wave impedance ratio data set, and the intermediate quantity data set M is ensured to be positive. A second coefficient is adjusted so that the difference between the model calculation quality parameter N and the model real quality parameter is within a preset range, and the adjusted target first coefficient A1 and the target second coefficient B1 are determined. The first target formula includes:

[0019] M = (T*A)-Z;

[0020] N = (M-M min )*B;

[0021] Wherein, the T is the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the forward seismic profile data, the A is the first coefficient, which is a constant, the Z is the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data in the forward seismic profile data, M is an intermediate quantity, the M min is the minimum value of M in the multiple plane positions, the B is the second coefficient, which is a constant, and the N is the model calculation quality parameter;

[0022] Based on the adjusted target first coefficient A1 and the target second coefficient B1, a second formula is determined, and the second formula includes:

[0023] M1 = (T1*A1)-Z1;

[0024] N1 = (M1-M 1min )*B1;

[0025] Wherein, the A1 is the target first coefficient, the B1 is the target second coefficient, the M1 is an intermediate quantity array obtained by calculating the actual data of the area to be studied, M 1min The T1 and Z1 of the second formula are used to determine the quality parameter N1 of each position in the area to be studied based on the time difference value data set T1 corresponding to two zero-phase layers adjacent to the strong reflection wave and the ratio data set Z1 of wave impedance values in the actual exploration seismic data corresponding to the area to be studied.

[0026] Optionally, after the second formula is determined based on the adjusted target first coefficient and the target second coefficient, the method further comprises:

[0027] Obtaining a longitudinal time difference value data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data corresponding to the area to be studied;

[0028] Performing sparse pulse inversion on the actual exploration seismic data corresponding to the area to be studied to obtain a wave impedance data set of the area to be studied;

[0029] Determining a wave impedance ratio data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the wave impedance data set of the area to be studied;

[0030] Determining the quality parameter of each position in the area to be studied through the time difference value data set, the wave impedance ratio data set of the actual exploration seismic data corresponding to the area to be studied, and the second formula.

[0031] Optionally, the forward operation of the forward geological model with the same dominant frequency of the actual exploration seismic data corresponding to the area to be studied to obtain the forward seismic profile data comprises:

[0032] Performing spectrum analysis on the actual exploration seismic data corresponding to the area to be studied to determine the dominant frequency, and then performing the forward operation of the forward geological model with the same dominant frequency to obtain the forward seismic profile data.

[0033] Optionally, the determination of the model real quality parameter Q based on the porosity of the forward geological model and the continuous thickness of the I-type reservoir comprises:

[0034] The determination of the model real quality parameter based on a third formula, the third formula comprising:

[0035] Q=K*h;

[0036] Wherein, the Q is the model real quality parameter, the K is the porosity of the forward geological model, and the h is the continuous thickness of the I-type reservoir.

[0037] Optionally, according to the logging data and the Class I reservoir classification data, a relationship among porosity, interval velocity and density in the reservoir of the area to be researched is obtained, comprising:

[0038] According to the logging data and the Class I reservoir classification data, a Longmaxi Formation-Wufeng Formation reservoir petrophysical model of the reservoir of the area to be researched is obtained;

[0039] Based on the reservoir petrophysical model, a relationship among porosity, interval velocity and density in the reservoir to be researched is determined.

[0040] In another aspect, a shale gas Class I reservoir quality parameter determination device is provided, comprising:

[0041] A first obtaining module is configured to obtain logging data, Class I reservoir classification data, geological layering data and actual exploration seismic data of real drilled wells in an area to be researched and a neighboring area;

[0042] A second obtaining module is configured to obtain a relationship among porosity, interval velocity and density in the reservoir of the area to be researched according to the logging data and the Class I reservoir classification data;

[0043] A first model establishing module is configured to establish a plurality of wedge-shaped models of different Class I reservoir continuous thicknesses and different porosities according to the relationship among porosity, interval velocity and density;

[0044] A second model establishing module is configured to establish a geological background model according to the geological layering data and acoustic logging velocity statistical data of the area to be researched;

[0045] A first embedding module is configured to embed the plurality of wedge-shaped models into the geological background model to obtain a forward geological model;

[0046] A forward module is configured to perform forward operation on the forward geological model with a same dominant frequency of a slant raylet of actual exploration seismic data corresponding to the area to be researched to obtain forward seismic profile data;

[0047] A first determining module is configured to calculate a longitudinal time difference data set corresponding to two zero-phase layers adjacent to a strong reflection wave in the forward seismic profile data, the time difference data set comprising longitudinal time differences corresponding to a plurality of planar positions in the two zero-phase layers;

[0048] A first inversion module is configured to perform sparse pulse inversion on the forward seismic profile data to obtain wave impedance profile data;

[0049] A second determining module is configured to determine a wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data;

[0050] a third obtaining module, configured to obtain porosity and a first type reservoir continuous thickness of the forward geology model

[0051] a third determining module, configured to determine a model real quality parameter Q based on the porosity of the forward geology model and the first type reservoir continuous thickness

[0052] a first adjusting module, configured to adjust a first coefficient based on the model real quality parameter and a first target formula, so that a product of the time difference value data set and the first coefficient is located in a same value range as the wave impedance ratio value data set, and ensure that each intermediate quantity data set M is positive; adjust a second coefficient, so that a difference between a model calculation quality parameter N and the model real quality parameter is within a preset range, and determine an adjusted target first coefficient A1 and a target second coefficient B1. The first target formula comprises:

[0053] M = (T*A)-Z

[0054] N = (M-M min )*B

[0055] wherein, the T is a longitudinal time difference value data set corresponding to two zero phase layers adjacent to a strong reflection wave in the forward seismic profile data, the A is the first coefficient, which is a constant, the Z is a wave impedance ratio value data set corresponding to the two zero phase layers adjacent to the strong reflection wave in the wave impedance profile data, M is an intermediate quantity, the M min is a minimum value of M in the plurality of plane positions, the B is the second coefficient, which is a constant, and the N is the model calculation quality parameter.

[0056] a fourth determining module, configured to determine a second formula based on the adjusted target first coefficient (A1) and the target second coefficient (B1), the second formula comprising:

[0057] M1 = (T1*A1)-Z1

[0058] N1 = (M1-M 1min )*B1

[0059] wherein, the A1 is the target first coefficient, the B1 is the target second coefficient, the M1 is an intermediate quantity array obtained by calculating actual data of the area to be studied, and M 1min is a minimum value in the intermediate quantity array, and the T1 and Z1 of the second formula are used to determine a quality parameter N1 of each position in the area to be studied based on a time difference value data set T1 and a wave impedance value ratio data set Z1 corresponding to two zero phase layers adjacent to a strong reflection wave in actual exploration seismic data corresponding to the area to be studied.

[0060] Optionally, the device further comprises:

[0061] a fourth obtaining module configured to obtain a longitudinal time difference data set corresponding to two zero-phase layers adjacent to a strong reflection wave in actual exploration seismic data corresponding to the area to be researched;

[0062] a second inversion module configured to perform sparse pulse inversion on the actual exploration seismic data corresponding to the area to be researched to obtain a wave impedance data set of the area to be researched;

[0063] a fifth determining module configured to determine a wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance data set of the area to be researched;

[0064] a first quality determining module configured to determine a quality parameter of each position in the area to be researched by using the time difference data set, the wave impedance ratio data set and the second formula.

[0065] Optionally, the forward modeling module comprises:

[0066] a forward modeling unit configured to perform spectrum analysis on the actual exploration seismic data corresponding to the area to be researched to determine a main frequency, and then perform forward modeling on the forward modeling geological model by using a same main frequency to obtain the forward modeling seismic profile data.

[0067] Optionally, the third determining module comprises:

[0068] a determining unit configured to determine the real quality parameter of the model based on a third formula, wherein the third formula comprises:

[0069] Q=K*h;

[0070] wherein the Q is the real quality parameter of the model, the K is the porosity of the forward modeling geological model, and the h is the continuous thickness of the Class I reservoir.

[0071] In another aspect, a storage medium is provided, wherein the storage medium stores at least one instruction, at least one program, a code set or an instruction set, and the at least one instruction, the at least one program, the code set or the instruction set are loaded and executed by a processor to implement the shale gas Class I reservoir quality parameter determination method as described above.

[0072] The technical scheme provided by the embodiments of the present application has at least the following beneficial effects:

[0073] Provided is a shale gas type I reservoir quality parameter determination method. Data obtained from a drilled well is processed to obtain a forward geology model and forward seismic profile data. A time difference data set is obtained based on the data, and wave impedance profile data is obtained by sparse pulse inversion of the forward seismic profile data. A wave impedance ratio data set is obtained based on the wave impedance profile data. A first formula is adjusted based on the time difference data set and the wave impedance ratio data set to obtain a second formula. The quality parameters of each position in a to-be-studied area can be obtained based on the second formula and actual exploration seismic data of the to-be-studied area. The method processes data through model forward and post-stack sparse pulse inversion, and does not need to directly process a large amount of original data, thereby solving the problems of large data processing amount, many parameters, and complex processes in the related art, achieving the effect of reducing data processing amount, and shortening the cycle of the entire technical process by about 75% compared with the pre-stack geostatistical inversion workflow. BRIEF DESCRIPTION OF DRAWINGS

[0074] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed in the embodiment description will be briefly introduced. Obviously, the drawings in the following description are only some embodiments of the present application, and other drawings can be obtained by those skilled in the art without creative effort.

[0075] Figure 1 is a flowchart of the shale gas type I reservoir quality parameter determination method provided by the embodiments of the present application;

[0076] Figure 2 is a schematic diagram of the relationship between interval velocity and porosity provided by the embodiments of the present application;

[0077] Figure 3 is a schematic diagram of the relationship between density and interval velocity provided by the embodiments of the present application;

[0078] Figure 4 is a schematic diagram of a wedge-shaped model with different continuous thicknesses and porosities of type I reservoirs provided by the embodiments of the present application;

[0079] Figure 5 is a schematic diagram of forward seismic profile data records provided by the embodiments of the present application;

[0080] Figure 6 is a schematic diagram of a zero-phase layer-wave peak upper zero value corresponding to a reflection time value provided by the embodiments of the present application;

[0081] Figure 7 is a schematic diagram of a zero-phase layer-wave peak lower zero value corresponding to a reflection time value provided by the embodiments of the present application;

[0082] Figure 8 is a schematic diagram of the reflection time difference value corresponding to two zero-phase layers provided by the embodiment of the present application;

[0083] Figure 9 is a schematic diagram of the wave impedance value corresponding to a zero-phase layer-wave peak upper zero value provided by the embodiment of the present application;

[0084] Figure 10 is a schematic diagram of the wave impedance value corresponding to a zero-phase layer-wave peak lower zero value provided by the embodiment of the present application;

[0085] Figure 11 is a schematic diagram of the ratio of the wave impedance values corresponding to two zero-phase layers provided by the embodiment of the present application;

[0086] Figure 12 is a schematic diagram of the porosity variation corresponding to nine groups of models provided by the embodiment of the present application;

[0087] Figure 13 is a schematic diagram of the thickness variation corresponding to nine groups of models provided by the embodiment of the present application;

[0088] Figure 14 is a schematic diagram of the quality parameter variation corresponding to nine groups of models provided by the embodiment of the present application;

[0089] Figure 15 is a schematic diagram of the M value variation provided by the embodiment of the present application;

[0090] Figure 16 is a schematic diagram of the relationship between the N value and the Q value provided by the embodiment of the present application;

[0091] Figure 17 is a schematic diagram of a shale gas type I reservoir quality parameter determination device provided by the embodiment of the present application;

[0092] Figure 18 is a schematic diagram of a forward modeling module provided by the embodiment of the present application;

[0093] Figure 19 is a schematic diagram of a third determination module provided by the embodiment of the present application.

[0094] The specific embodiments of the present application have been shown in the above-described drawings, and will be described in more detail hereinafter. These drawings and textual descriptions are not intended to limit the scope of the concept of the present application by any means, but to illustrate the concept of the present application to those skilled in the art by referring to specific embodiments. DETAILED DESCRIPTION

[0095] In order to make the purpose, technical solutions and advantages of the present application more clear, the embodiments of the present application will be described in more detail below with reference to the drawings.

[0096] Figure 1 is a flow chart of a shale gas type I reservoir quality parameter determination method shown in an embodiment of the present application. The shale gas type I reservoir quality parameter determination method can include the following steps:

[0097] Step 1001, obtaining well logging data, type I reservoir classification data, geological layering data and actual exploration seismic data of real drilled wells in a to-be-studied area and adjacent areas.

[0098] That is, first, obtaining various data of real drilled wells in the to-be-studied area and adjacent areas (areas adjacent to the to-be-studied area) for standby use. The quality parameter conditions of the shale gas type I reservoir (a reservoir with organic carbon content greater than 3%, effective porosity greater than 5%, brittle mineral content greater than 55%, and gas content greater than 3 tons / m 3 The quality parameter conditions of the shale gas type I reservoir in the to-be-studied area can be obtained first from the corresponding well logging data, type I reservoir classification data, geological layering data and actual exploration seismic data of real drilled wells in the to-be-studied area. The type I reservoir classification data includes organic carbon content, porosity, brittle mineral content, etc. of the reservoir. The geological layering data includes the depth and thickness of each reservoir.

[0099] Step 1002, obtaining the relationship among porosity, interval velocity and density in the reservoir of the to-be-studied area according to the well logging data and the type I reservoir classification data.

[0100] The relationship among porosity, interval velocity and density in the reservoir of the to-be-studied area can include the relationship between porosity and interval velocity and the relationship between porosity and density. The porosity refers to the ratio of the sum of all pore space volumes in a rock sample to the volume of the rock sample, which is called the total porosity of the rock and is expressed in percentage. The greater the total porosity of the reservoir, the greater the pore space in the rock. The interval velocity refers to the velocity of seismic wave propagation in the layered reservoir.

[0101] Optionally, step 1002 includes step A and step B.

[0102] Step A, obtaining a Longmaxi Formation-Wufeng Formation reservoir rock physics model of the reservoir of the to-be-studied area according to the well logging data and the type I reservoir classification data.

[0103] For example, the Longmaxi Formation-Wufeng Formation reservoir rock physics model can be established according to the data obtained in step 1001.

[0104] Step B, determining the relationship among porosity, interval velocity and density in the reservoir of the to-be-studied area based on the reservoir rock physics model.

[0105] For example, please refer to Table 1, Figure 2 andFigure 3 The actual drilled well in the area, the continuous thickness of the Class I reservoir, porosity, and velocity can be shown in Table 1, as shown in Figure 2 , Figure 2 The relationship between the velocity and the porosity is shown in Figure 3 , Figure 3 The relationship between the density and the velocity is shown in

[0106] Table 1: Rock physical parameters of drilled wells in a shale gas working area in the South of Sichuan

[0107]

[0108]

[0109] For example, as shown in the well Q in Table 1 above, the continuous thickness of the Class I reservoir at this location is 8.30 meters, the porosity is 4.64%, the velocity is 4221.61 m / s, and the density is 2.53 g / cm 3 .

[0110] Step 1003: According to the relationship between the porosity, the velocity, and the density, a plurality of wedge models with different continuous thicknesses of the Class I reservoir and different porosities are established.

[0111] As shown in Figure 4 , Figure 4 The wedge models with different continuous thicknesses of the Class I reservoir and different porosities are shown in the figure, in which the horizontal coordinate is the position coordinate in the reservoir, and the vertical coordinate is the depth, both in meters.

[0112] For example, according to the distribution range of the continuous thickness of the Class I reservoir and the porosity parameters revealed by the data obtained in step 1001, the wedge models with different continuous thicknesses of the Class I reservoir and different porosities can be established. In the present embodiment, nine models can be established, the porosity changes in the range of 4% to 7.5%, and the thickness of each model changes in the range of 0 to 40 m, which contains all possible cases of the current reservoir thickness and porosity changes.

[0113] Step 1004: According to the geological stratification data and the acoustic logging velocity statistical data of the area to be studied, a geological background model is established.

[0114] According to the geological stratification data and the acoustic logging velocity statistical data of the area to be studied, a geological background model can be established. The model can include the velocity and the density of the reservoir surrounding rock, the reservoir thickness, and other data.

[0115] Step 1005, embedding the plurality of wedge models into the geological background model to obtain a forward geological model.

[0116] Embedding the nine wedge models obtained in step 1003 into the geological background model obtained in step 1004, so that the forward geological model can be obtained.

[0117] Step 1006, performing forward operation on the forward geological model with the same main frequency of the actual exploration seismic data corresponding to the area to be studied to obtain forward seismic profile data.

[0118] Optionally, the forward seismic profile data can be obtained by performing forward operation on the forward geological model with the same main frequency of the actual exploration seismic data corresponding to the area to be studied.

[0119] For example, the forward seismic profile data can be obtained by performing forward operation on the forward geological model obtained in step 1005 with a 30Hz Ricker wavelet. The forward seismic profile data refers to the reflection waveform data of the underground rock interface formed by digital simulation of the seismic acquisition and processing flow.

[0120] Step 1007, calculating a longitudinal time difference data set corresponding to two zero-phase layers adjacent to a strong reflection wave in the forward seismic profile data, the time difference data set including longitudinal time differences corresponding to a plurality of plane positions in the two zero-phase layers.

[0121] In the embodiments of the present application, please refer to Figure 5 , Figure 6 , Figure 7 and Figure 8 , Figure 5 , Figure 6 , Figure 7 and Figure 8 , the horizontal coordinate is the position in the reservoir (unit: meter), and the vertical coordinate is time (unit: second). As shown in Figure 5 , Figure 5 is a schematic diagram of the forward seismic profile data record. As shown in Figure 6 , Figure 6 is a schematic diagram of the reflection time value corresponding to the zero value on the wave peak of a zero-phase layer provided by the embodiments of the present application, as shown in Figure 7 , Figure 7 is a schematic diagram of the reflection time value corresponding to the zero value below the wave peak of a zero-phase layer provided by the embodiments of the present application, as shown in Figure 8 , Figure 8A schematic diagram of the reflection time difference values corresponding to the two zero-phase layers provided by the embodiment of the present application is shown. Due to the large difference in rock physical parameters between the five peak groups and the pagoda group, the rock physical parameters include P-wave velocity, S-wave velocity, density, Poisson's ratio, etc., and strong amplitude reflection can be formed. At the same time, the weak amplitude changes caused by the continuous thickness and porosity changes of the reservoir I type reservoir will be hidden in the strong amplitude reflection background, so that the corresponding time and time difference data set of the two zero-phase layers adjacent to the strong reflection wave can be obtained by interpreting the strong reflection zero-phase layer according to the seismic profile data determined in step 1006 (wherein the zero-phase layer includes the zero value above the wave peak and the zero value below the wave peak, that is, the two zero-phase layers adjacent to the strong reflection wave), and the time difference value is the difference between the corresponding longitudinal position time of the zero value above the wave peak and the zero value below the wave peak at the same strong reflection position. The time difference data set can include multiple data sets, and each data set can include a position in a reservoir and a time difference value corresponding to the position in the reservoir (the difference between the time value corresponding to the zero value above the wave peak and the time value corresponding to the zero value below the wave peak at the same horizontal position in the reservoir).

[0122] Step 1008, sparse pulse inversion is performed on the forward seismic profile data to obtain wave impedance profile data.

[0123] Sparse pulse inversion is performed on the forward seismic profile data obtained in step 1006, wherein the sparse pulse inversion is a recursive inversion method based on sparse pulse deconvolution, and wave impedance profile data can be obtained.

[0124] Step 1009, determine the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data.

[0125] The wave impedance ratio data set includes the ratio of the wave impedance value corresponding to the zero value above the wave peak and the wave impedance value corresponding to the zero value below the wave peak at each same horizontal position. For example, the wave impedance ratio data set can include multiple data sets, and each data set can include a plane position and a wave impedance ratio corresponding to the plane position (the ratio of the wave impedance value corresponding to the zero value above the wave peak and the wave impedance value corresponding to the zero value below the wave peak at the same plane position). Please refer to Figure 9 、 Figure 10 and Figure 11 , Figure 9 and Figure 10 The horizontal coordinate is the plane position number, and the vertical coordinate is the wave impedance value. Figure 11 The horizontal coordinate is the plane position number, and the vertical coordinate is the wave impedance value. As shown in Figure 9 , Figure 9 A schematic diagram of the wave impedance value corresponding to the zero-phase layer-wave peak above zero value provided by the embodiment of the present application is shown. As shown in Figure 10 , Figure 10A schematic diagram of the wave impedance value corresponding to the zero value of the zero-phase layer-wave peak is provided for the embodiments of the present application. As shown in Figure 11 Figure 11 A schematic diagram of the ratio of the wave impedance values corresponding to the two zero-phase layers is provided for the embodiments of the present application. According to the zero-phase layer adjacent to the strong reflected wave in step 1007, the wave impedance value of the corresponding layer can be extracted from the wave impedance data body obtained in step 1008, and the ratio of the two wave impedance values corresponding to the two zero-phase layers adjacent to the strong reflected wave in the wave impedance data body can be determined.

[0126] Step 1010, obtaining the porosity and the continuous thickness of the type I reservoir of the forward geology model.

[0127] Please refer to Figure 12 and Figure 13 . As shown in Figure 12 Figure 12 A schematic diagram of the porosity variation corresponding to the nine-group model is provided for the embodiments of the present application, Figure 12 wherein the horizontal coordinate is the plane position number and the vertical coordinate is the porosity value. As shown in Figure 13 Figure 13 A schematic diagram of the thickness variation corresponding to the nine-group model is provided for the embodiments of the present application, Figure 13 wherein the horizontal coordinate is the plane position number and the vertical coordinate is the thickness value. According to the forward geology model obtained in step 1005, the data variation schematic diagram of the porosity and the continuous thickness of the type I reservoir is obtained.

[0128] Step 1011, determining the model real quality parameter Q based on the porosity and the continuous thickness of the type I reservoir of the forward geology model.

[0129] Optionally, the model real quality parameter can be determined based on a third formula, and the third formula comprises:

[0130] Q=K*h;

[0131] wherein Q is the model real quality parameter, K is the porosity of the forward geology model, and h is the continuous thickness of the type I reservoir. Through the third formula and the porosity and the continuous thickness of the type I reservoir at a certain position, the model real quality parameter can be determined.

[0132] As shown in Figure 14 Figure 14 ​​​​This application provides a schematic diagram illustrating the changes in actual quality parameters corresponding to nine sets of models, where the horizontal axis represents the planar location number and the vertical axis represents the quality parameter value. This application provides a method for calculating the quality parameter Q, namely the third formula: Q = K * h. The actual quality parameter is the product of porosity and the continuous thickness of the Class I reservoir in the forward geological model. In this application embodiment, the actual quality parameter Q of the model can be calculated based on the porosity K and the continuous thickness h of the Class I reservoir obtained in step 1010.

[0133] Step 1012: Based on the model's actual quality parameters and the first target formula, adjust the first coefficient so that the product of the time difference data set and the first coefficient, and the wave impedance ratio data set are within the same value range, and ensure that the intermediate quantity data set M are all positive values; adjust the second coefficient so that the difference between the model's calculated quality parameter N and the model's actual quality parameter is within a preset range, and determine the adjusted target first coefficient A1 and target second coefficient B1.

[0134] The first objective formula includes:

[0135] M = (T*A) - Z;

[0136] N = (MM) min )*B;

[0137] Where T represents the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the forward seismic profile data, A is the first coefficient, which is a constant, Z represents the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data in the forward seismic profile data, and M is an intermediate quantity, M min M is the minimum value among multiple planar positions, B is the second coefficient, and N is the model quality parameter calculated by the first formula.

[0138] Please refer to Figure 15 as well as Figure 16 .like Figure 15 As shown, Figure 15 This is a schematic diagram illustrating the change of the M value in an embodiment of this application. Figure 15 The horizontal axis represents the planar location number, and the vertical axis represents the M value. For example... Figure 16 As shown, Figure 16 This illustration shows the relationship between N value (the model quality parameter calculated using the first formula) and Q value (the actual quality parameter corresponding to the forward geological model) in an embodiment of this application. Figure 16The horizontal coordinate is the plane position number, and the vertical coordinate is the quality parameter value. The dashed line in the figure represents the N value (the model quality parameter calculated by the first formula), and the solid line represents the Q value (the real quality parameter corresponding to the forward geological model). Since the time difference value T corresponding to the two zero-phase layers adjacent to the strong reflection wave obtained in step 1007 and the ratio Z of the two wave impedance values corresponding to the two zero-phase layers adjacent to the strong reflection wave determined in step 1009 are not in the same value range, where the same value range can mean that the values of the two data differ by less than ten times, if the values of the two data differ by equal to or more than ten times, they are not in the same value range, the first coefficient A can be adjusted so that the product of the time difference value T and the first coefficient A differs from the value of the wave impedance ratio Z by less than ten times, so that the time difference value T and the wave impedance ratio Z are in the same value range, and the value of T*A should be greater than the wave impedance ratio Z, that is, the value of M is always positive. Thus, the minimum value M of M in a series of M data can be selected from a plurality of positions min , and the quality parameter N of the model is calculated.

[0139] The embodiment of the present application provides a calculation method of the simulated quality parameter N, that is, N = (M-M min )*B. The second coefficient B is adjusted so that the difference between the simulated quality parameter N (the model quality parameter calculated by the first formula) and the quality parameter Q (the real quality parameter corresponding to the forward geological model) determined in step 1011 is within a preset range. Generally, the difference between N and Q can be within 10%. The first coefficient A and the second coefficient B are adjusted, and when the difference between the model quality parameter N and the real model quality parameter Q is within the preset range, the values of A and B at this time are recorded as the adjusted first coefficient A1 and the second coefficient B1.

[0140] In step 1013, the second formula is determined based on the adjusted target first coefficient A1 and the target second coefficient B1.

[0141] The second formula includes:

[0142] M1 = (T1*A1)-Z1;

[0143] N1 = (M1-M 1min )*B1;

[0144] Wherein, A1 is the target first coefficient, B1 is the target second coefficient, M1 is the intermediate quantity array obtained by calculating the actual data of the area to be studied, and M 1min is the minimum value in the intermediate quantity array. The T1 and Z1 of the second formula are used to determine the quality parameter N1 of each position in the area to be studied based on the time difference value data group T1 corresponding to the two zero-phase layers adjacent to the strong reflection wave and the ratio data group Z1 of the wave impedance values in the actual exploration seismic data corresponding to the area to be studied.

[0145] Wherein, A1 and B1 are the first coefficient A and the second coefficient B adjusted in step 1012.

[0146] Step 1014, obtaining a longitudinal time difference data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data corresponding to the area to be researched.

[0147] The process of this step can refer to steps 1007-1009 described above. The embodiments of the present application will not be repeated here.

[0148] Step 1015, performing sparse pulse inversion on the actual exploration seismic data corresponding to the area to be researched to obtain a wave impedance data set of the area to be researched.

[0149] In this step, sparse pulse inversion can be performed on the actual exploration seismic data in step 1014 to obtain a wave impedance data set of the area to be researched. Wherein, sparse pulse inversion is a recursive inversion method based on sparse pulse deconvolution, which can obtain a wave impedance data set.

[0150] Step 1016, determining a wave impedance ratio data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the wave impedance data set of the area to be researched.

[0151] The specific determination method can refer to step 1009.

[0152] Step 1017, determining the quality parameter of each position in the area to be researched by the time difference data set, the wave impedance ratio data set and the second formula of the actual exploration seismic data corresponding to the area to be researched.

[0153] This step uses the second formula in step 1013, directly takes the target first coefficient and the target second coefficient obtained after adjustment in step 1012, and brings the time difference data set and the wave impedance ratio data set of the actual exploration seismic data corresponding to the area to be researched into the second formula, so as to determine the quality parameter of each position in the area to be researched.

[0154] In summary, the embodiment of the present application provides a shale gas type I reservoir quality parameter determination method, which obtains forward geology model by processing data obtained from actual drilling, and obtains forward seismic profile data, obtains a time difference value data set based on the data, and obtains wave impedance profile data by sparse pulse inversion on the forward seismic profile data, obtains a wave impedance ratio data set based on the wave impedance profile data, and then adjusts the first formula based on the time difference value data set and the wave impedance ratio data set to obtain the second formula, and subsequently, the quality parameters of each position in the to-be-studied area can be obtained based on the second formula and actual exploration seismic data of the to-be-studied area. The method processes data through model forward and post-stack sparse pulse inversion, compared with the way of processing data through pre-stack geology statistics inversion in the related art, does not need to directly process a large amount of original data, solves the problems of large amount of data processing, multiple parameters and complex process in the related art, realizes the effect of reducing the amount of data processing, and the whole technical process of the present application shortens the process cycle by about 75% compared with the pre-stack geology statistics inversion work process.

[0155] Figure 17 FIG. 1 is a schematic diagram of a shale gas type I reservoir quality parameter determination device 10 provided by the embodiment of the present application, which comprises the following modules:

[0156] The first obtaining module 101 is configured to obtain well logging data, type I reservoir division data, geology layering data and actual exploration seismic data of actual drilling in the to-be-studied area and adjacent areas;

[0157] The second obtaining module 102 is configured to obtain the relationship among porosity, interval velocity and density in the reservoir of the to-be-studied area according to the well logging data and the type I reservoir division data;

[0158] The first model establishing module 103 is configured to establish a plurality of wedge-shaped models with different type I reservoir continuous thicknesses and different porosities according to the relationship among porosity, interval velocity and density;

[0159] The second model establishing module 104 is configured to establish a geology background model according to the geology layering data and acoustic logging velocity statistical data of the to-be-studied area;

[0160] The first embedding module 105 is configured to embed the plurality of wedge-shaped models into the geology background model to obtain a forward geology model;

[0161] The forward module 106 is configured to perform forward operation on the forward geology model by using the same Ricker wavelet with the same main frequency as the actual exploration seismic data of the to-be-studied area to obtain forward seismic profile data;

[0162] The first determining module 107 is configured to calculate, in the forward seismic profile data, a longitudinal time difference data set corresponding to two zero-phase layers adjacent to a strong reflection wave, and the time difference data set includes longitudinal time difference values corresponding to a plurality of plane positions in the two zero-phase layers;

[0163] The first inversion module 108 is configured to perform sparse pulse inversion on the forward seismic profile data to obtain wave impedance data;

[0164] The second determining module 109 is configured to determine a wave impedance ratio data set of two wave impedance values corresponding to the same plane position in the wave impedance data set of the two zero-phase layers adjacent to the strong reflection wave;

[0165] The third obtaining module 110 is configured to obtain porosity and continuous thickness of the Class I reservoir of the forward geological model;

[0166] The third determining module 111 is configured to determine a model real quality parameter Q based on the porosity and the continuous thickness of the Class I reservoir of the forward geological model;

[0167] The first adjusting module 112 is configured to adjust a first coefficient based on the model real quality parameter and a first target formula, so that a product of the time difference data set and the first coefficient is in the same value range as the wave impedance ratio data set, and the intermediate quantity data set M is ensured to be positive; adjust a second coefficient, so that a difference between a model calculation quality parameter N and the model real quality parameter is within a preset range, and determine an adjusted target first coefficient A1 and a target second coefficient B1. The first target formula includes:

[0168] M = (T*A)-Z;

[0169] N = (M-M min )*B;

[0170] The T is a longitudinal time difference data set corresponding to two zero-phase layers adjacent to a strong reflection wave in the forward seismic profile data, the A is the first coefficient, which is a constant, the Z is a wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data in the forward seismic profile data, M is an intermediate quantity, the M min is a minimum value of M in the plurality of plane positions, the B is a second coefficient, which is a constant, and the N is a model calculation quality parameter.

[0171] The fourth determining module 113 is configured to determine a second formula based on the adjusted target first coefficient A1 and the target second coefficient B1. The second formula includes:

[0172] M1 = (T1*A1)-Z1;

[0173] N1 = (M1-M 1min)*B1;

[0174] wherein, A1 is a target first coefficient, B1 is a target second coefficient, M1 is an intermediate quantity array obtained by calculating actual data of the area to be researched, M 1min is a minimum value in the intermediate quantity array, T1 and Z1 of the second formula are used to determine the quality parameter N1 of each position in the area to be researched based on the time difference value data set T1 corresponding to two zero-phase layers adjacent to the strong reflection wave and the ratio data set Z1 of the wave impedance value corresponding to the actual exploration seismic data of the area to be researched.

[0175] The fourth acquisition module 114 is configured to acquire a longitudinal time difference value data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data of the area to be researched.

[0176] The second inversion module 115 is configured to perform sparse pulse inversion on the actual exploration seismic data of the area to be researched to obtain a wave impedance data body of the area to be researched.

[0177] The fifth determination module 116 is configured to determine a wave impedance ratio data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the wave impedance data body of the area to be researched.

[0178] The first quality determination module 117 is configured to determine the quality parameter of each position in the area to be researched by the time difference value data set, the wave impedance ratio data set and the second formula of the actual exploration seismic data of the area to be researched.

[0179] In summary, the embodiment of the present application provides a shale gas type I reservoir quality parameter determination device. The data obtained from the actual drilling well is processed to obtain a forward geology model and forward seismic profile data. A time difference value data set is obtained based on the data. The wave impedance profile data is obtained by performing sparse pulse inversion on the forward seismic profile data. A wave impedance ratio data set is obtained based on the wave impedance profile data. Then, the first formula is adjusted based on the time difference value data set and the wave impedance ratio data set to obtain the second formula. The quality parameter of each position in the area to be researched can be obtained based on the second formula and the actual exploration seismic data of the area to be researched. The method processes the data by model forward and post-stack sparse pulse inversion. Compared with the way of processing data by pre-stack geostatistical inversion in the related art, the method does not need to directly process a large amount of original data, solves the problems of large data processing amount, many parameters and complex process in the related art, realizes the effect of reducing the data processing amount, and shortens the cycle of the whole technical process by about 75% compared with the pre-stack geostatistical inversion workflow.

[0180] Figure 18 A schematic diagram of a forward module 106 provided by the embodiment of the present application is shown in the figure. The forward module 106 includes a forward unit 1061:

[0181] The forward unit 1061 is configured to perform spectrum analysis on actual exploration seismic data corresponding to the area to be researched, determine a main frequency, and perform forward operation on a forward geological model by using a Ricker wavelet with the same main frequency to obtain forward seismic profile data.

[0182] Figure 19 A third determination module 111 provided in the embodiment of the present application includes a determination unit 1111.

[0183] The determination unit 1111 is configured to determine a model real quality parameter Q based on a third formula. The third formula includes:

[0184] Q = K * h.

[0185] Wherein, Q is the model real quality parameter, K is the porosity of the forward geological model, and h is the continuous thickness of the Class I reservoir.

[0186] In summary, the embodiment of the present application provides a shale gas Class I reservoir quality parameter determination device. The data obtained from the actual drilling well is processed to obtain a forward geological model and forward seismic profile data. A time difference value data set is obtained based on the data. The wave impedance profile data is obtained by performing sparse pulse inversion on the forward seismic profile data. The wave impedance ratio data set is obtained based on the wave impedance profile data. Then, the first formula is adjusted based on the time difference value data set and the wave impedance ratio data set to obtain the second formula. Subsequently, the quality parameters of each position in the area to be researched can be obtained based on the second formula and the actual exploration seismic data of the area to be researched. The method processes the data by model forward and post-stack sparse pulse inversion. Compared with the way of processing data by pre-stack geostatistical inversion in the related art, the method does not need to directly process a large amount of original data, solves the problems of large data processing amount, multiple parameters, and complex process in the related art, achieves the effect of reducing the data processing amount, and shortens the cycle of the whole technical process by about 75% compared with the pre-stack geostatistical inversion workflow.

[0187] In addition, the embodiment of the present application further provides a computer storage medium, and the computer storage medium stores at least one instruction, at least one program, a code set or an instruction set. The at least one instruction, the at least one program, the code set or the instruction set is loaded and executed by a processor to implement the shale gas Class I reservoir distribution determination method as required.

[0188] In the present application, the terms "first", "second", "third" and "fourth" are only used for descriptive purposes, and cannot be understood as indicating or implying relative importance. The term "multiple" refers to two or more, unless otherwise explicitly limited.

[0189] The above merely provides the optional embodiments of the present application, and is not intended to limit the present application. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining quality parameters of Class I shale gas reservoirs, characterized in that, The method includes: Obtain logging data from actual wells drilled in the study area and adjacent areas, Class I reservoir classification data, geological stratification data, and actual exploration seismic data; Based on the well logging data and the Class I reservoir classification data, the relationship between porosity, layer velocity and density in the reservoir of the study area is obtained; Based on the relationship between porosity, layer velocity, and density, multiple wedge models with different continuous thicknesses and different porosities of Class I reservoirs are established. A geological background model is established based on the geological stratification data and sonic logging velocity statistics of the area to be studied. By embedding the multiple wedge-shaped models into the geological background model, a forward geological model is obtained; The forward modeling geological model is performed using a Ricker wavelet with the same dominant frequency as the actual exploration seismic data corresponding to the area to be studied to obtain forward modeling seismic profile data. In the forward-modeled seismic profile data, the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave is calculated. The time difference data set includes the longitudinal time difference corresponding to multiple planar positions in the two zero-phase layers. Sparse pulse inversion is performed on the forward modeled seismic profile data to obtain wave impedance profile data; Determine the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflected wave in the wave impedance profile data. Obtain the porosity and continuous thickness of Class I reservoirs from the forward geological model; The true quality parameter Q of the model is determined based on the porosity of the forward geological model and the continuous thickness of the Class I reservoir. Based on the model's actual quality parameters and the first target formula, the first coefficient is adjusted so that the product of the time difference data set and the first coefficient, and the wave impedance ratio data set, are within the same value range, and that the intermediate quantity data set M is always positive; the second coefficient is adjusted so that the difference between the model's calculated quality parameter N and the model's actual quality parameter is within a preset range, and the adjusted target first coefficient A1 and target second coefficient B1 are determined; wherein, the first target formula includes: M = (T*A) - Z; N=(M-M min )*B; Wherein, T represents the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the forward seismic profile data; A is the first coefficient, which is a constant; Z represents the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data; and M is an intermediate quantity. min M is the minimum value among the multiple planar positions, B is the second coefficient, is a constant, and N is the model calculation quality parameter; Based on the adjusted target first coefficient A1 and target second coefficient B1, a second formula is determined, wherein the second formula includes: M1 = (T1*A1) - Z1; N1=(M1-M 1min )*B1; Wherein, A1 is the target first coefficient, B1 is the target second coefficient, and M1 is an intermediate quantity array calculated from the actual data of the area under study. 1min The minimum value in the intermediate quantity array is T1 and Z1 in the second formula. Based on the time difference data set T1 and the wave impedance ratio data set Z1 of the two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data corresponding to the area under study, the quality parameter N1 at each location in the area under study is determined.

2. The method according to claim 1, characterized in that, After determining the second formula based on the adjusted target first coefficient and target second coefficient, the method further includes: Obtain the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data of the area to be studied; Sparse pulse inversion is performed on the actual exploration seismic data corresponding to the area to be studied to obtain the wave impedance data volume of the area to be studied. In the wave impedance data volume of the area under study, determine the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflected wave; The quality parameters of each location in the study area are determined by using the time difference data set, wave impedance ratio data set, and the second formula of the actual exploration seismic data corresponding to the study area.

3. The method according to claim 1, characterized in that, The forward modeling geological model is performed using a Ricker wavelet with the same dominant frequency as the actual exploration seismic data corresponding to the area under study to obtain forward modeled seismic profile data, including: Spectral analysis is performed on the actual exploration seismic data corresponding to the area to be studied to determine the dominant frequency. Then, the forward modeling geological model is performed using the Ricker wavelet with the same dominant frequency to obtain the forward modeling seismic profile data.

4. The method according to claim 1, characterized in that, The determination of the true quality parameter Q of the model based on the porosity of the forward geological model and the continuous thickness of the Class I reservoir includes: The true quality parameters of the model are determined based on a third formula, which includes: Q = K * h; Wherein, Q is the true quality parameter of the model, K is the porosity of the forward geological model, and h is the continuous thickness of the Class I reservoir.

5. The method according to claim 1, characterized in that, Based on the well logging data and the Class I reservoir classification data, the relationship between porosity, layer velocity, and density in the reservoir of the study area is obtained, including: Based on the well logging data and the Class I reservoir classification data, the reservoir petrophysical model of the Longmaxi Formation-Wufeng Formation in the area to be studied is obtained. Based on the reservoir rock physics model, the relationship between porosity, layer velocity, and density in the reservoir under study is determined.

6. A device for determining the quality parameters of Class I shale gas reservoirs, characterized in that, The device includes: The first acquisition module is used to acquire logging data from actual wells drilled in the study area and adjacent areas, Class I reservoir classification data, geological stratification data, and actual exploration seismic data. The second acquisition module is used to acquire the relationship between porosity, layer velocity and density in the reservoir of the area to be studied based on the well logging data and the Class I reservoir classification data. The first model building module establishes multiple wedge-shaped models with different continuous thicknesses and different porosities of different type I reservoirs based on the relationship between porosity, layer velocity and density. The second model building module is used to build a geological background model based on the geological stratification data and sonic logging velocity statistics of the area to be studied. The first embedding module is used to embed the plurality of wedge-shaped models into the geological background model to obtain a forward geological model; The forward modeling module is used to perform forward modeling operations on the forward geological model using the Ricker wavelet with the same dominant frequency as the actual exploration seismic data corresponding to the area under study, so as to obtain forward seismic profile data. The first determining module is used to calculate the longitudinal time difference data set corresponding to two zero-phase layers adjacent to the strong reflection wave in the forward seismic profile data. The time difference data set includes longitudinal time differences corresponding to multiple planar positions in the two zero-phase layers. The first inversion module is used to perform sparse pulse inversion on the forward seismic profile data to obtain wave impedance profile data. The second determining module is used to determine the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflected wave in the wave impedance profile data. The third acquisition module is used to acquire the porosity and continuous thickness of Class I reservoirs in the forward geological model. The third determining module is used to determine the true quality parameter Q of the model based on the porosity of the forward geological model and the continuous thickness of the Class I reservoir; The first adjustment module is used to adjust a first coefficient based on the model's actual quality parameters and a first target formula, so that the product of the time difference data set and the first coefficient, and the wave impedance ratio data set, are within the same value range, and that all intermediate quantity data sets M are positive; adjust a second coefficient so that the difference between the model's calculated quality parameter N and the model's actual quality parameter is within a preset range, and determine the adjusted target first coefficient A1 and target second coefficient B1; wherein, the first target formula includes: M = (T*A) - Z; N=(M-M min )*B; Wherein, T represents the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the forward seismic profile data; A is the first coefficient, which is a constant; Z represents the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the wave impedance profile data; and M is an intermediate quantity. min M is the minimum value among the multiple planar positions, B is the second coefficient, is a constant, and N is the model calculation quality parameter; The fourth determining module is used to determine the second formula based on the adjusted target first coefficient A1 and target second coefficient B1, the second formula including: M1 = (T1*A1) - Z1; N1=(M1-M 1min )*B1; Wherein, A1 is the target first coefficient, B1 is the target second coefficient, and M1 is an intermediate quantity array calculated from the actual data of the area under study. 1min The minimum value in the intermediate quantity array is T1 and Z1 in the second formula. Based on the time difference data set T1 and the wave impedance ratio data set Z1 of the two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data corresponding to the area under study, the quality parameter N1 at each location in the area under study is determined.

7. The device for determining the quality parameters of a Class I shale gas reservoir according to claim 6, the device further comprising: The fourth acquisition module is used to acquire the longitudinal time difference data set corresponding to the two zero-phase layers adjacent to the strong reflection wave in the actual exploration seismic data corresponding to the area to be studied. The second inversion module is used to perform sparse pulse inversion on the actual exploration seismic data corresponding to the area to be studied, and obtain the wave impedance data volume of the area to be studied. The fifth determining module is used to determine the wave impedance ratio data set corresponding to the two zero-phase layers adjacent to the strong reflected wave in the wave impedance data volume of the area under study. The first quality determination module is used to determine the quality parameters of each location in the area under study by using the time difference data set, the wave impedance ratio data set, and the second formula of the actual exploration seismic data corresponding to the area under study.

8. The device for determining the quality parameters of a Class I shale gas reservoir according to claim 6, wherein the forward modeling module comprises: The forward modeling unit is used to perform spectral analysis on the actual exploration seismic data corresponding to the area to be studied, determine the dominant frequency, and then perform forward modeling calculations on the forward geological model using the same dominant frequency of the Rick wavelet to obtain the forward modeling seismic profile data.

9. The device for determining the quality parameters of a Class I shale gas reservoir according to claim 6, wherein the third determining module comprises: The determining unit is used to determine the true quality parameters of the model based on a third formula, wherein the third formula includes: Q = K * h; Wherein, Q is the true quality parameter of the model, K is the porosity of the forward geological model, and h is the continuous thickness of the Class I reservoir.

10. A storage medium, characterized in that, The storage medium stores at least one instruction, at least one program, code set, or instruction set, wherein the at least one instruction, the at least one program, the code set, or instruction set is loaded and executed by a processor to implement the method for determining the quality parameters of shale gas Class I reservoirs as described in any one of claims 1 to 5.

Images