Method, apparatus, storage medium and electronic device for determining reservoir

Abstract

The present application relates to the technical field of geological exploration, and specifically relates to a method, device and electronic device for determining a reservoir. The method can establish a low-frequency model based on seismic data and logging data of strata in a target area; perform inversion based on the low-frequency model to obtain the relative impedance body of the strata, and the relative impedance body can reflect information such as the lithology and physical properties of the strata; then update the low-frequency model according to the relative impedance body to obtain a target low-frequency model, and the data of the reservoir can be accurately obtained by using the target low-frequency model. Therefore, post-stack impedance inversion is performed on the new low-frequency model to obtain the longitudinal wave impedance data of the strata, and the longitudinal wave impedance data can be used to accurately determine the reservoir, so as to accurately characterize the reservoir.

Description

Technical Field

[0001] This application relates to the technical field of geological exploration, and particularly to a method, device, storage medium, and electronic device for determining a reservoir. Background Art

[0002] The main body of Tahe Oilfield is an Ordovician carbonate fractured-vuggy reservoir. The main reservoir body type is a fractured-vuggy reservoir. The reservoir body is controlled by karst and fractures, with a complex morphology, strong vertical and horizontal heterogeneity, a deep burial depth (exceeding 5300m), and weak seismic signals. Its exploration and development are extremely difficult. Through the forward modeling study of the carbonate reservoir model in Tahe Oilfield and the analysis of the actual seismic reflection characteristics of the reservoir, the typical beaded strong-amplitude seismic reflection structure is mainly composed of the multiple waves (dipole oscillation) between the reservoir body and the dense surrounding rock and the stronger short-axis reflection formed after the diffraction wave is migrated and positioned. The most typical reflection characteristic of the fractured-vuggy reservoir body on seismic data is the "beaded" reflection, and its seismic anomaly range is much larger than the actual fracture and vug size. Therefore, it is difficult to accurately predict the distribution pattern, size, and spatial position of the fracture and vug body using seismic reflection characteristics.

[0003] Currently, the main method for predicting karst-vuggy carbonate reservoirs is to find "beaded" strong reflections based on post-stack seismic data to determine karst-vuggy reservoirs. Due to the deep burial depth of the target layer, complex surface conditions, and low signal-to-noise ratio of the target layer's seismic data, there is a problem of insufficient ability to identify the "beaded" seismic reflections of carbonate karst-vuggy reservoirs, resulting in relatively low drilling success rates and exploration and development efficiencies. Summary of the Invention

[0004] In view of the above problems, this application provides a method, device, storage medium, and electronic device for determining a reservoir.

[0005] In a first aspect, this application provides a method for determining a reservoir, the method comprising:

[0006] Establish a low-frequency model based on the seismic data and logging data of the formation in the target area obtained;

[0007] Perform inversion based on the low-frequency model to obtain the relative impedance body of the formation;

[0008] Update the low-frequency model according to the relative impedance body to obtain a target low-frequency model;

[0009] Perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0010] In the above-described embodiment, a low-frequency model is established based on seismic data and well logging data of the formation in the target area, and then the low-frequency model is inverted to obtain the relative impedance body of the formation. The relative impedance body can reflect information such as the lithology and physical properties of the formation. Then, the low-frequency model is updated according to the relative impedance body. After establishing a new low-frequency model, post-stack impedance inversion is performed on the new low-frequency model to obtain formation P-wave impedance data, so as to accurately determine the reservoir using the P-wave impedance data.

[0011] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, the establishing a low-frequency model based on the obtained seismic data and well logging data of the formation in the target area includes:

[0012] Establishing a time-depth relationship through well-seismic calibration based on the obtained well logging data and seismic data;

[0013] Establishing a framework model of the clastic rock formation in the formation according to the time-depth relationship;

[0014] Determining P-wave impedance data and background P-wave impedance data in the depth direction of the formation according to the well logging data;

[0015] Performing lateral interpolation on the framework model using the P-wave impedance data to obtain a low-frequency impedance model of the clastic rock formation;

[0016] Based on the background P-wave impedance value, determining a background low-frequency P-wave impedance model of the carbonate rock formation in the formation;

[0017] Determining a low-frequency model based on the low-frequency impedance model and the background low-frequency P-wave impedance model.

[0018] In the above-described embodiment, the outliers in the seismic data in the carbonate rock formation can reflect the changes in the reservoir, eliminating the false appearance caused by the anomalies in the low-frequency model interpolated in the well and truly reflecting the actual situation underground.

[0019] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, the well logging data includes: acoustic wave data and density data of a single well, and the seismic data includes: seismic wavelet data. The establishing a time-depth relationship through well-seismic calibration based on the obtained well logging data and seismic data includes:

[0020] Determining a reflection coefficient based on the acoustic wave data and density data of a single well;

[0021] Convolving the reflection coefficient and the seismic wavelet to obtain a synthetic seismic record;

[0022] Establishing the time-depth relationship based on the synthetic seismic record.

[0023] In the above embodiments, the well data is in the depth domain and the seismic data is in the time domain. The reflection coefficient is obtained from the acoustic wave and density data of a single well, and the synthetic seismic record is obtained by convolving the seismic wavelet with the reflection coefficient. The synthetic record section is calibrated with the seismic section passing through the well to convert the data in the depth domain to the time domain. The synthetic seismic record obtained by convolving the reflection coefficient with the seismic wavelet can accurately establish the time-depth relationship, thereby ensuring the accurate determination of the reservoir.

[0024] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, performing inversion based on the low-frequency model to obtain the relative impedance body of the formation includes:

[0025] Performing constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain the relative impedance body of the formation.

[0026] In the above embodiments, performing inversion on the low-frequency model according to the seismic data can make full use of the information such as structure, horizon, and lithology provided by the seismic data and well logging data to convert the change of the conventional seismic reflection amplitude into the relative impedance body of the formation, so as to accurately reflect the lithology, physical properties, etc. of the formation.

[0027] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, updating the low-frequency model according to the relative impedance body to obtain a target low-frequency model includes:

[0028] Setting the value of the relative impedance body corresponding to the clastic rock formation to a null value and retaining the negative value in the value of the relative impedance body corresponding to the carbonate rock formation to obtain a negative impedance model;

[0029] Adding the negative impedance model to the low-frequency model to obtain a target low-frequency model.

[0030] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, performing inversion based on the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data includes:

[0031] Performing constrained sparse pulse inversion on the target low-frequency model based on the seismic data to obtain the longitudinal wave impedance data of the formation;

[0032] Determining target longitudinal wave impedance data based on the longitudinal wave impedance data and the longitudinal wave impedance threshold;

[0033] Determining the spatial position corresponding to the target longitudinal wave impedance data as the reservoir in the formation.

[0034] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, the determining the target P-wave impedance data based on the P-wave impedance data and the P-wave impedance threshold includes:

[0035] Comparing the magnitudes of the P-wave impedance data and the P-wave impedance threshold;

[0036] Determining the part of the P-wave impedance data that is less than the P-wave impedance threshold as the target P-wave impedance data.

[0037] In a second aspect, the present application provides a device for determining a reservoir. The device includes: a low-frequency model establishment module for establishing a low-frequency model according to seismic data and well logging data of a formation in a target area;

[0038] A relative impedance body acquisition module for performing inversion based on the low-frequency model to obtain the relative impedance body of the formation;

[0039] A target low-frequency model acquisition module for updating the low-frequency model according to the relative impedance body to obtain a target low-frequency model;

[0040] A reservoir determination module for performing inversion according to the target low-frequency model to determine the P-wave impedance data of the formation, so as to determine the reservoir in the formation based on the P-wave impedance data.

[0041] In the above embodiment, a low-frequency model is established according to seismic data and well logging data of a formation in a target area, and then inversion is performed on the low-frequency model to obtain the relative impedance body of the formation. The relative impedance body can reflect information such as the lithology and physical properties of the formation. Then, the low-frequency model is updated according to the relative impedance body. After establishing a new low-frequency model, post-stack impedance inversion is performed on the new low-frequency model to obtain the P-wave impedance data of the formation, so as to accurately determine the reservoir using the P-wave impedance data.

[0042] According to an embodiment of the present application, optionally, in the above device for determining a reservoir, the low-frequency model establishment module includes:

[0043] A well-seismic calibration unit for performing well-seismic calibration based on the acquired well logging data and seismic data to establish a time-depth relationship;

[0044] A framework model establishment unit for establishing a framework model of the clastic rock formation in the formation according to the time-depth relationship;

[0045] An impedance data determination unit for determining the P-wave impedance data and background P-wave impedance data in the depth direction of the formation according to the well logging data;

[0046] A low-frequency impedance model acquisition unit, configured to perform lateral interpolation on the framework model by using the longitudinal wave impedance data to obtain a low-frequency impedance model of the clastic rock formation;

[0047] A background low-frequency longitudinal wave impedance model acquisition unit, configured to determine a background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation based on the background longitudinal wave impedance value;

[0048] A low-frequency model determination unit, configured to determine a low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model.

[0049] In the above embodiments, the outliers in the seismic data in the carbonate rock formation can reflect the changes in the reservoir, eliminating the false appearance caused by the anomalies of the low-frequency model interpolated in the well, and truly reflecting the actual situation underground.

[0050] According to an embodiment of the present application, optionally, in the above reservoir determination device, the well logging data includes: acoustic wave data and density data of a single well, the seismic data includes: seismic wavelet data, and the well-seismic calibration unit includes:

[0051] A reflection coefficient determination subunit, configured to determine a reflection coefficient based on the acoustic wave data and density data of a single well;

[0052] A synthetic seismogram acquisition subunit, configured to perform convolution on the reflection coefficient and the seismic wavelet to obtain a synthetic seismogram;

[0053] A time-depth relationship establishment subunit, configured to establish the time-depth relationship based on the synthetic seismogram.

[0054] In the above embodiments, the well data is in the depth domain and the seismic data is in the time domain. The reflection coefficient is obtained from the acoustic wave and density data of a single well, the synthetic seismogram is obtained by convolving the seismic wavelet and the reflection coefficient, and the synthetic record section is calibrated with the seismic section passing through the well to convert the data in the depth domain to the time domain. The synthetic seismogram obtained by convolving the reflection coefficient and the seismic wavelet can accurately establish the time-depth relationship, thereby ensuring the accurate determination of the reservoir.

[0055] According to an embodiment of the present application, optionally, in the above reservoir determination device, the relative impedance body acquisition module includes:

[0056] A relative impedance body determination unit, configured to perform constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain a relative impedance body of the formation.

[0057] In the above embodiments, the inversion of the low-frequency model based on seismic data can make full use of the structural, horizon, lithology and other information provided by seismic data and logging data to convert the change of conventional seismic reflection amplitude into the relative impedance body of the formation, so as to accurately reflect the lithology, physical properties and other information of the formation.

[0058] According to an embodiment of the present application, optionally, in the above reservoir determination device, the target low-frequency model acquisition module includes:

[0059] A negative impedance model acquisition unit, configured to set the value of the relative impedance body corresponding to the clastic rock formation as a null value, and retain the negative value in the value of the relative impedance body corresponding to the carbonate rock formation to obtain a negative impedance model;

[0060] A target low-frequency model acquisition unit, configured to add the negative impedance model and the low-frequency model to obtain a target low-frequency model.

[0061] According to an embodiment of the present application, optionally, in the above reservoir determination device, the reservoir determination module includes:

[0062] A P-wave impedance data acquisition unit, configured to perform constrained sparse pulse inversion on the seismic data using the target low-frequency model to obtain the P-wave impedance data of the formation;

[0063] A target P-wave impedance data determination unit, configured to determine target P-wave impedance data based on the P-wave impedance data and a P-wave impedance threshold;

[0064] A reservoir determination unit, configured to determine the spatial position corresponding to the target P-wave impedance data as the reservoir in the formation.

[0065] According to an embodiment of the present application, optionally, in the above reservoir determination device, the target P-wave impedance data determination unit includes:

[0066] A comparison subunit, configured to compare the magnitudes of the P-wave impedance data and the P-wave impedance threshold;

[0067] A target P-wave impedance data determination subunit, configured to determine the part of the P-wave impedance data that is less than the P-wave impedance threshold as the target P-wave impedance data.

[0068] In a third aspect, the present application provides a storage medium, and a computer program stored in the storage medium can be executed by one or more processors and can be used to implement the above reservoir determination method.

[0069] In a fourth aspect, the present application provides an electronic device, including a memory and a processor, and a computer program is stored on the memory. When the computer program is executed by the processor, the above reservoir determination method is executed.

[0070] Compared with the prior art, one or more embodiments in the above solution may have the following advantages or beneficial effects:

[0071] A method, device, storage medium and electronic device for determining a reservoir provided by the present application. The method can establish a low-frequency model based on seismic data and logging data of a formation in a target area; perform inversion based on the low-frequency model to obtain the relative impedance body of the formation; update the low-frequency model according to the relative impedance body to obtain a target low-frequency model; perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data. By establishing a low-frequency model based on seismic data and logging data of a formation in a target area, and then performing inversion on the low-frequency model to obtain the relative impedance body of the formation, the relative impedance body can reflect information such as the lithology and physical properties of the formation. Then, update the low-frequency model according to the relative impedance body, establish a new low-frequency model and then perform post-stack impedance inversion on the new low-frequency model to obtain the longitudinal wave impedance data of the formation, so as to accurately determine the reservoir by using the longitudinal wave impedance data. BRIEF DESCRIPTION OF THE DRAWINGS

[0072] Hereinafter, the present application will be described in more detail based on embodiments and with reference to the drawings.

[0073] Figure 1 It is a schematic flow chart of a method for determining a reservoir provided in Embodiment 1 of the present application.

[0074] Figure 2 It is a schematic block diagram of a structure of a device for determining a reservoir provided in Embodiment 6 of the present application.

[0075] Figure 3 It is a connection block diagram of an electronic device provided in Embodiment 8 of the present application.

[0076] In the drawings, the same components are denoted by the same reference numerals, and the drawings are not drawn to actual scale. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0077] Hereinafter, the embodiments of the present application will be described in detail with reference to the drawings and embodiments, so as to fully understand how the present application uses technical means to solve technical problems and the implementation process of achieving corresponding technical effects for implementation. Each feature in the embodiments of the present application and in the embodiments can be combined with each other on the premise of not conflicting, and the formed technical solutions are all within the protection scope of the present application.

[0078] Example 1

[0079] The present invention provides a method for determining a reservoir. Please refer to Figure 1, the method includes the following steps:

[0080] Step S110: Establish a low-frequency model based on the seismic data and well logging data of the strata in the target area obtained.

[0081] Based on the seismic data and well logging data, a low-frequency model that basically reflects the geological characteristics of the sediment body can be established. The low-frequency model can be obtained by interpolating and extrapolating the well logging data within the entire data volume with the constraints of the seismic data interpretation horizons and sedimentation laws. In addition, the low-frequency model can also be established by combining the seismic velocity spectrum information in the seismic data with the well logging data, which can compensate for the missing low-frequency information in the seismic data to a certain extent. When establishing the low-frequency model based on the seismic data and well logging data, well curves with better quality in the well logging data can be selected and interpolated according to a certain algorithm under the constraints of horizons, faults, etc., such as the weight method, Kriging, inverse distance weighting, etc. In addition to establishing the low-frequency model by means of seismic velocity conversion mentioned above, a low-frequency model can also be established by single well interpolation. By comparing the differences between the forward synthetic seismogram and the original seismic data, pseudo-wells can be added at the places with large differences to change the low-frequency model information, and a relatively real low-frequency model can be obtained through continuous updating. In order to consider the seismic reflection characteristics, different lithology and fluid boundaries can also be delineated by attributes such as seismic amplitude and frequency, and different elastic properties can be defined for each facies belt to obtain the low-frequency model.

[0082] Step S120: Perform inversion based on the low-frequency model to obtain the relative impedance body of the strata.

[0083] According to an embodiment of the present application, step S120 includes the following steps:

[0084] Step S121: Perform constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain the relative impedance body of the strata.

[0085] Performing inversion on the low-frequency model according to the seismic data can make full use of the information such as structure, horizons, and lithology provided by the seismic data and well logging data to convert the changes in the conventional seismic reflection amplitude into the relative impedance body of the strata, so as to reflect the lithology, physical properties, etc. of the strata.

[0086] Specifically, the seismic data can be carefully processed first to extract parameters such as seismic bodies and seismic wavelets, and then constrained sparse pulse inversion can be performed on the low-frequency model. Constrained sparse pulse inversion is a recursive seismic wave impedance inversion method. Constrained sparse pulse inversion broadens the effective frequency band width of the input seismic data by adjusting the sparsity of the reflection coefficient sequence and obtains an elastic parameter model and a sparsity constraint factor. Seismic signal-to-noise ratio, combined frequency, and wavelet scaling factor are the key parameters in this algorithm. The seismic signal-to-noise ratio is used to constrain the similarity between the inversion result and the seismic data. The higher the signal-to-noise ratio is set, the more relevant the synthetic seismogram converted from the inversion result is to the seismic data, and vice versa. The sparsity constraint factor is the sparsity of the reflection coefficient sequence. The smaller the value of the sparsity constraint factor, the sparser the reflection coefficient sequence.

[0087] Step S130: Update the low-frequency model according to the relative impedance body to obtain a target low-frequency model.

[0088] The relative impedance body preserves amplitude, that is, it is faithful to the amplitude recorded in the original seismic data. In addition, the relative impedance body corresponds well to the equivalent reservoir, that is, its spatial position corresponds well to the equivalent layer of multiple reservoirs, which can ensure that the updated low-frequency model obtained according to the relative impedance body is more accurate. There are positive and negative values in the relative impedance body obtained in step S120. The impedance values corresponding to above the top surface of the carbonate rock formation (T74 interface) in the relative impedance body are set as null values, the positive part below the T74 interface is set as null values, and the negative part is retained, so that a negative impedance model of the carbonate rock formation below the T74 interface can be obtained. Then, add the low-frequency model established in step S110 and the negative impedance model retaining the negative part to obtain a new low-frequency impedance model, that is, the target low-frequency model.

[0089] Step S140: Invert according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0090] Updating the low-frequency model according to the relative impedance body obtained by inverting the low-frequency model established in step S110 can make the obtained target low-frequency model more accurate. Then invert according to the target low-frequency model to determine the longitudinal wave impedance data of the formation. The longitudinal wave impedance data can reflect the anisotropic variation law. Therefore, the reservoir in the formation can be accurately characterized based on the longitudinal wave impedance data.

[0091] In summary, the present application provides a method for determining a reservoir, including: establishing a low-frequency model based on seismic data and logging data of a formation in a target area; performing inversion based on the low-frequency model to obtain a relative impedance body of the formation; updating the low-frequency model according to the relative impedance body to obtain a target low-frequency model; performing inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data. A low-frequency model is established based on seismic data and logging data of a formation in a target area, and then inversion is performed on the low-frequency model to obtain a relative impedance body of the formation. The relative impedance body can reflect information such as the lithology and physical properties of the formation. Then, the low-frequency model is updated according to the relative impedance body. After establishing a new low-frequency model, post-stack impedance inversion is performed on the new low-frequency model to obtain the longitudinal wave impedance data of the formation, so as to accurately determine the reservoir using the longitudinal wave impedance data.

[0092] Example 2

[0093] On the basis of Embodiment 1, this embodiment illustrates the method in Embodiment 1 through a specific implementation case.

[0094] The method for determining a reservoir provided by the present application includes:

[0095] Step S110: Establish a low-frequency model based on seismic data and logging data of a formation in a target area obtained;

[0096] Step S120: Perform inversion based on the low-frequency model to obtain a relative impedance body of the formation;

[0097] Step S130: Update the low-frequency model according to the relative impedance body to obtain a target low-frequency model;

[0098] Step S140: Perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0099] Among them, in the above method for determining a reservoir, the step S110 includes the following steps:

[0100] Step S1110: Establish a time-depth relationship through well-seismic calibration based on the obtained logging data and seismic data.

[0101] Using seismic data and well logging data, the structure of the reservoir can be interpreted and the reservoir can be predicted to finely describe the oil reservoir. However, the longitudinal scale described by well logging data is depth, and the profile described by seismic data is time scale. Since the two data description methods are different, they cannot be directly jointly applied and need to be calibrated based on the well-seismic calibration between well logging data and seismic data. When performing well-seismic calibration, it can be calibrated based on the waveform correlation between the synthetic seismic record in the seismic data and the seismic trace beside the well. In addition, the reflection coefficient can be calculated through acoustic wave and density well logging data, and the synthetic seismic record similar to the seismic trace can be constructed by convolving the emission coefficient with the wavelet. Then, by comparing the synthetic seismic record with the seismic trace beside the well, the calibration result can be adjusted to achieve well-seismic calibration. For example, the sample well in the target area can be determined first, and the synthetic seismic record in the single-well depth domain can be obtained based on this sample well. Then, according to the synthetic seismic record in the single-well depth domain, the corresponding relationship between time and depth at the single well can be established. Next, the geological horizons of the single well are converted from the depth domain to the time domain to establish a geological horizon model in the time domain. Finally, the remaining well horizons in the study area are automatically matched to the geological horizon model in the time domain, so as to achieve the rapid well-seismic calibration work for all wells.

[0102] Step S1120: Establish a framework model of the clastic rock formation in the formation according to the time-depth relationship.

[0103] The time-depth relationship obtained from well-seismic calibration can map the different geological interfaces analyzed by single-well analysis to the seismic section, that is, from the depth domain to the time domain. Therefore, seismic data can be used to spatially trace different geological interfaces to obtain the spatial distribution of geological interfaces, and a framework model of the formation can be established using these different geological interfaces.

[0104] Step S1130: Determine the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the well logging data.

[0105] Step S1140: Horizontally interpolate the framework model using the longitudinal wave impedance data to obtain the low-frequency impedance model of the clastic rock formation.

[0106] Step S1150: Determine the background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation based on the background longitudinal wave impedance value.

[0107] Step S1160: Determine the low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model.

[0108] Under the constraint of the framework model, the longitudinal wave impedance values of different single wells in the vertical direction are interpolated horizontally to obtain the low-frequency impedance model interpolated in the well. Since carbonate rocks are highly heterogeneous horizontally, the model interpolated horizontally from a single well cannot reflect the characteristics of the lateral distribution of carbonate rock formations. Therefore, the low-frequency model interpolated in the well can be used for the clastic rock formation above the top surface of the carbonate rock (T74 seismic reflection interface); below T74 is the carbonate rock formation, and the background longitudinal wave impedance value of the carbonate rock formation is used to replace the low-frequency model, that is, the low-frequency model of the carbonate rock formation part is a constant straight low-frequency model. Among them, the background longitudinal wave impedance value can be represented by a constant here to represent the carbonate rock background value. Through the above method, the abnormal values in the seismic data in the carbonate rock formation can reflect the changes in the reservoir, eliminating the false appearance caused by the abnormality of the low-frequency model interpolated in the well and truly reflecting the actual situation underground.

[0109] Example 3

[0110] On the basis of Embodiment 1, this embodiment illustrates the method in Embodiment 1 through a specific implementation case.

[0111] The method for determining a reservoir provided by this application includes:

[0112] Step S110: Establish a low-frequency model based on the seismic data and well logging data of the formation in the target area obtained;

[0113] Step S120: Perform inversion based on the low-frequency model to obtain the relative impedance body of the formation;

[0114] Step S130: Update the low-frequency model according to the relative impedance body to obtain a target low-frequency model;

[0115] Step S140: Perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0116] Step S110 includes the following steps:

[0117] Step S1110: Establish a time-depth relationship based on the obtained well logging data and seismic data through well-seismic calibration.

[0118] Step S1120: Establish a framework model of the clastic rock formation in the formation according to the time-depth relationship.

[0119] Step S1130: Determine the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the well logging data.

[0120] Step S1140: Horizontally interpolate the framework model using the longitudinal wave impedance data to obtain the low-frequency impedance model of the clastic rock formation.

[0121] Step S1150: Determine the background low-frequency longitudinal wave impedance model of the carbonate formation in the formation based on the background longitudinal wave impedance value.

[0122] Step S1160: Determine the low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model.

[0123] Among them, in the above reservoir determination method, the logging data includes: acoustic wave data and density data of a single well, the seismic data includes: seismic wavelet data, and the step S1110 includes the following steps:

[0124] Step S1111: Determine the reflection coefficient based on the acoustic wave data and density data of a single well.

[0125] After converting the time-domain wavelet to the depth domain, due to the influence of velocity, the waveform undergoes two changes: compression or stretching with depth. Therefore, the reflection coefficient can be calculated based on the acoustic wave data and density data. When calculating the reflection coefficient, the main frequency of the wavelet should be calculated from the well-side seismic trace with good quality on the depth migration section, and a zero-phase wavelet should be selected. Before calculating the reflection coefficient, the acoustic wave travel-time curve and density curve should be corrected and outliers should be removed.

[0126] Step S1112: Convolve the reflection coefficient and the seismic wavelet to obtain the synthetic seismic record.

[0127] Convolution, also known as convolution, is a mathematical method of integral transformation. It is a mathematical operator that generates a third function through two functions, representing the integral of the product of the function values of the overlapping part after flipping and translation of the two functions over the overlapping length. The synthetic seismic record obtained through convolution is a seismic record artificially synthesized and converted from acoustic logging or vertical seismic profile data, that is, a seismic trace. It is a very widely used method in seismic model technology and is also the basis for work such as horizon calibration and reservoir description. It is the intermediate medium for converting the geological model into seismic information. The synthetic seismic record is the bridge connecting high-resolution logging information and regional seismic information, and its accuracy directly affects the accurate calibration of geological horizons.

[0128] Step S1113: Establish the time-depth relationship based on the synthetic seismic record.

[0129] Well data is in the depth domain, while seismic data is in the time domain. Reflection coefficients are obtained from the acoustic wave and density data of a single well. The synthetic seismic record is obtained by convolving the seismic wavelet with the reflection coefficients. The synthetic record section is calibrated with the seismic section passing through the well to convert the data from the depth domain to the time domain. The synthetic seismic record obtained by convolving the reflection coefficients and the seismic wavelet can accurately establish the time-depth relationship, thus ensuring the accurate determination of the reservoir.

[0130] Example 4

[0131] Based on Example 1, this example illustrates the method in Example 1 through a specific implementation case.

[0132] The method for determining a reservoir provided by this application includes:

[0133] Step S110: Establish a low-frequency model based on the seismic data and well logging data of the formation in the target area obtained;

[0134] Step S120: Invert based on the low-frequency model to obtain the relative impedance body of the formation;

[0135] Step S130: Update the low-frequency model according to the relative impedance body to obtain the target low-frequency model;

[0136] Step S140: Invert according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0137] Among them, in the above method for determining a reservoir, step S130 includes the following steps:

[0138] Step S131: Set the values of the relative impedance body corresponding to the clastic rock formation as null values, and retain the negative values of the relative impedance body corresponding to the carbonate rock formation to obtain a negative impedance model.

[0139] Specifically, in step S120, there are positive and negative values in the relative impedance body obtained by inverting the low-frequency model. The impedance values above the top surface of the carbonate rock formation (T74 interface) can be set as null values, the positive part below the T74 interface can be set as null values, and the negative part below the T74 interface is retained, then the negative impedance model of the carbonate rock formation below the T74 interface can be obtained.

[0140] Step S132: Add the negative impedance model and the low-frequency model to obtain the target low-frequency model.

[0141] Then, add the low-frequency model established in step S110 and the negative impedance model that retains the negative value part to obtain a new low-frequency model, that is, the target low-frequency model. That is to say, the vacant part of the positive value below the T74 interface in the negative impedance model is set to a null value, and the negative impedance model is used to replace it, and the target low-frequency model can be obtained.

[0142] Example 5

[0143] On the basis of Embodiment 1, this embodiment illustrates the method in Embodiment 1 through specific implementation cases.

[0144] The reservoir determination method provided by this application includes:

[0145] Step S110: Establish a low-frequency model according to the seismic data and logging data of the formation in the target area obtained;

[0146] Step S120: Perform inversion based on the low-frequency model to obtain the relative impedance body of the formation;

[0147] Step S130: Update the low-frequency model according to the relative impedance body to obtain the target low-frequency model;

[0148] Step S140: Perform inversion according to the target low-frequency model to determine the P-wave impedance data of the formation, so as to determine the reservoir in the formation based on the P-wave impedance data.

[0149] Among them, in the above reservoir determination method, step S140 includes the following steps:

[0150] Step S141: Perform constrained sparse pulse inversion based on the seismic data using the target low-frequency model to obtain the P-wave impedance data of the formation.

[0151] The inversion of the low-frequency model in step S120 and the inversion of the target low-frequency model in step S140 can be the same inversion method. For example, both inversions can be performed by the constrained sparse pulse inversion method.

[0152] Step S142: Determine the target P-wave impedance data based on the P-wave impedance data and the P-wave impedance threshold.

[0153] After obtaining the inversion result through constrained sparse pulse inversion, the longitudinal wave impedance threshold can be obtained. When obtaining the longitudinal wave impedance threshold, according to the cave layer reservoir actually drilled, through well-seismic calibration, the longitudinal wave impedance value corresponding to the position of the "bead-shaped" reflection corresponding to the cave layer reservoir on the inverted longitudinal wave impedance profile can be determined. Combining the longitudinal wave impedance value corresponding to the cave layer reservoir obtained from the actual drilled well, the longitudinal wave impedance threshold of the cave layer reservoir is determined. Then, according to the longitudinal wave impedance data and the longitudinal wave impedance threshold, the target longitudinal wave impedance data is determined from the longitudinal wave impedance data.

[0154] Step S143: Determine the spatial position corresponding to the target longitudinal wave impedance data as the reservoir in the formation.

[0155] Relative longitudinal wave impedance bodies and full-band longitudinal wave impedance bodies can be obtained in the results of both inversions. After obtaining the relative longitudinal wave impedance body and the full-band longitudinal wave impedance body in step S120, in step S130, the relative longitudinal wave impedance body among them, that is, the relative impedance body, is used to establish a new low-frequency model. After the sparse pulse inversion performed in step 140, only the obtained full-band longitudinal wave impedance body is used to depict the cave reservoir.

[0156] According to an embodiment of the present application, optionally, in the above method for determining a reservoir, step S142 includes:

[0157] Step S1421: Compare the magnitudes of the longitudinal wave impedance data and the longitudinal wave impedance threshold;

[0158] Step S1422: Determine the part of the longitudinal wave impedance data that is less than the longitudinal wave impedance threshold as the target longitudinal wave impedance data.

[0159] Specifically, in a carbonate rock formation, the longitudinal wave impedance data less than this longitudinal wave impedance threshold is determined as the target longitudinal wave impedance data of the cave layer reservoir. Constrained sparse pulse inversion is performed on the target low-frequency model according to the longitudinal wave impedance threshold to depict the longitudinal wave impedance data of the formation. The part of the longitudinal wave impedance data that is less than the longitudinal wave impedance threshold is retained and determined as the target longitudinal wave impedance data, and the part of the longitudinal wave impedance data that is greater than the longitudinal wave impedance threshold is discarded. Thus, the space of the reservoir can be depicted based on the retained part of the target longitudinal wave impedance data.

[0160] Example 6

[0161] Please refer to Figure 2 , the present application provides a device 200 for determining a reservoir, and the device includes:

[0162] A low-frequency model establishment module 210, configured to establish a low-frequency model according to the seismic data and well logging data of the formation in the obtained target area;

[0163] The relative impedance body acquisition module 220 is configured to perform inversion based on the low-frequency model to obtain the relative impedance body of the formation;

[0164] The target low-frequency model acquisition module 230 is configured to update the low-frequency model according to the relative impedance body to obtain a target low-frequency model;

[0165] The reservoir determination module 240 is configured to perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

[0166] According to an embodiment of the present application, optionally, in the above reservoir determination device, the low-frequency model establishment module 210 includes:

[0167] The well-seismic calibration unit is configured to establish a time-depth relationship based on the acquired well logging data and seismic data for well-seismic calibration;

[0168] The framework model establishment unit is configured to establish a framework model of the clastic rock formation in the formation according to the time-depth relationship;

[0169] The impedance data determination unit is configured to determine the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the well logging data;

[0170] The low-frequency impedance model acquisition unit is configured to perform lateral interpolation on the framework model by using the longitudinal wave impedance data to obtain a low-frequency impedance model of the clastic rock formation;

[0171] The background low-frequency longitudinal wave impedance model acquisition unit is configured to determine a background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation based on the background longitudinal wave impedance value;

[0172] The low-frequency model determination unit is configured to determine a low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model.

[0173] According to an embodiment of the present application, optionally, in the above reservoir determination device, the well logging data includes: acoustic wave data and density data of a single well, and the seismic data includes: seismic wavelet data. The well-seismic calibration unit includes:

[0174] The reflection coefficient determination subunit is configured to determine a reflection coefficient based on the acoustic wave data and density data of a single well;

[0175] The synthetic seismic record acquisition subunit is configured to perform convolution on the reflection coefficient and the seismic wavelet to obtain a synthetic seismic record;

[0176] The time-depth relationship establishment subunit is configured to establish the time-depth relationship based on the synthetic seismic record.

[0177] According to an embodiment of the present application, optionally, in the above reservoir determination device, the relative impedance body acquisition module 220 includes:

[0178] A relative impedance body determination unit, configured to perform constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain the relative impedance body of the formation.

[0179] According to an embodiment of the present application, optionally, in the above reservoir determination device, the target low-frequency model acquisition module includes:

[0180] A negative impedance model acquisition unit, configured to set the value of the relative impedance body corresponding to the clastic rock formation to a null value and retain the negative value in the value of the relative impedance body corresponding to the carbonate rock formation to obtain a negative impedance model;

[0181] A target low-frequency model acquisition unit, configured to add the negative impedance model and the low-frequency model to obtain a target low-frequency model.

[0182] According to an embodiment of the present application, optionally, in the above reservoir determination device, the reservoir determination module 240 includes:

[0183] A P-wave impedance data acquisition unit, configured to perform constrained sparse pulse inversion on the seismic data using the target low-frequency model to obtain the P-wave impedance data of the formation;

[0184] A target P-wave impedance data determination unit, configured to determine target P-wave impedance data based on the P-wave impedance data and a P-wave impedance threshold;

[0185] A reservoir determination unit, configured to determine the spatial position corresponding to the target P-wave impedance data as the reservoir in the formation.

[0186] According to an embodiment of the present application, optionally, in the above reservoir determination device, the target P-wave impedance data determination unit includes:

[0187] A comparison subunit, configured to compare the magnitudes of the P-wave impedance data and the P-wave impedance threshold;

[0188] A target P-wave impedance data determination subunit, configured to determine the part of the P-wave impedance data that is less than the P-wave impedance threshold as the target P-wave impedance data.

[0189] In summary, the present application provides a reservoir determination device, including: a low-frequency model establishment module 210, configured to establish a low-frequency model according to seismic data and logging data of a formation in a target area; a relative impedance body acquisition module 220, configured to perform inversion based on the low-frequency model to obtain a relative impedance body of the formation; a target low-frequency model acquisition module 230, configured to update the low-frequency model according to the relative impedance body to obtain a target low-frequency model; and a reservoir determination module 240, configured to perform inversion according to the target low-frequency model to determine longitudinal wave impedance data of the formation, so as to determine a reservoir in the formation based on the longitudinal wave impedance data. A low-frequency model is established according to seismic data and logging data of a formation in a target area, and then inversion is performed on the low-frequency model to obtain a relative impedance body of the formation. The relative impedance body can reflect information such as lithology and physical properties of the formation. Then, the low-frequency model is updated according to the relative impedance body, and after a new low-frequency model is established, post-stack impedance inversion is performed on the new low-frequency model to obtain longitudinal wave impedance data of the formation, so as to accurately determine a reservoir by using the longitudinal wave impedance data.

[0190] Example 7

[0191] This embodiment further provides a computer-readable storage medium, such as a flash memory, a hard disk, a multimedia card, a card-type memory (for example, an SD or DX memory, etc.), a random access memory (RAM), a static random access memory (SRAM), a read-only memory (ROM), an electrically erasable programmable read-only memory (EEPROM), a programmable read-only memory (PROM), a magnetic memory, a magnetic disk, an optical disc, a server, an App application store, etc., on which a computer program is stored. When the computer program is executed by a processor, the following method steps can be implemented:

[0192] Step S110: Establish a low-frequency model according to seismic data and logging data of a formation in a target area obtained;

[0193] Step S120: Perform inversion based on the low-frequency model to obtain a relative impedance body of the formation.

[0194] Step S130: Update the low-frequency model according to the relative impedance body to obtain a target low-frequency model.

[0195] Step S140: Perform inversion according to the target low-frequency model to determine longitudinal wave impedance data of the formation, so as to determine a reservoir in the formation based on the longitudinal wave impedance data.

[0196] Optionally, in the above reservoir determination method, step S110 includes the following steps:

[0197] Establish a time-depth relationship through well-seismic calibration based on the obtained logging data and seismic data;

[0198] Establish a framework model of the clastic rock formation in the formation according to the time-depth relationship;

[0199] Determine the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the logging data;

[0200] Use the longitudinal wave impedance data to perform lateral interpolation on the framework model to obtain the low-frequency impedance model of the clastic rock formation;

[0201] Based on the background longitudinal wave impedance value, determine the background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation;

[0202] Determine the low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model.

[0203] Optionally, in the above method for determining the reservoir, the logging data includes: acoustic wave data and density data of a single well, and the seismic data includes: seismic wavelet data. The establishment of the time-depth relationship by well-seismic calibration based on the obtained logging data and seismic data includes the following steps:

[0204] Determine the reflection coefficient based on the acoustic wave data and density data of a single well;

[0205] Convolve the reflection coefficient and the seismic wavelet to obtain a synthetic seismogram;

[0206] Establish the time-depth relationship based on the synthetic seismogram.

[0207] Optionally, in the above method for determining the reservoir, step S120 includes the following steps:

[0208] Perform constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain the relative impedance body of the formation.

[0209] Optionally, in the above method for determining the reservoir, step S130 includes the following steps:

[0210] Set the value corresponding to the clastic rock formation in the relative impedance body to a null value, and retain the negative value in the value corresponding to the carbonate rock formation in the relative impedance body to obtain a negative value impedance model;

[0211] Add the negative value impedance model to the low-frequency model to obtain the target low-frequency model.

[0212] Optionally, in the above method for determining the reservoir, step S140 includes the following steps:

[0213] Performing constrained sparse pulse inversion on the seismic data using the target low-frequency model to obtain the P-wave impedance data of the formation;

[0214] Based on the P-wave impedance data and the P-wave impedance threshold, determining the target P-wave impedance data;

[0215] Determining the spatial position corresponding to the target P-wave impedance data as the reservoir in the formation.

[0216] Optionally, in the above method for determining the reservoir, the step of determining the target P-wave impedance data based on the P-wave impedance data and the P-wave impedance threshold includes:

[0217] Comparing the magnitudes of the P-wave impedance data and the P-wave impedance threshold;

[0218] Determining the part of the P-wave impedance data that is less than the P-wave impedance threshold as the target P-wave impedance data.

[0219] For the specific implementation process of the above method steps, reference can be made to Embodiment 1, and this embodiment will not be repeated here.

[0220] Example 8

[0221] An embodiment of the present application provides an electronic device, which can be a mobile phone, a computer, a tablet computer, etc., including a memory and a processor. A calculator program is stored on the memory, and when the computer program is executed by the processor, it implements the method for determining the reservoir as described in Embodiment 1. It can be understood that as Figure 3 shown, the electronic device 300 may further include: a processor 301, a memory 302, a multimedia component 303, an input / output (I / O) interface 304, and a communication component 305.

[0222] Among them, the processor 301 is used to execute all or part of the steps in the method for determining the reservoir in Embodiment 1. The memory 302 is used to store various types of data, which may include, for example, instructions of any application program or method in the electronic device, as well as data related to the application program.

[0223] The processor 301 can be implemented by an application specific integrated circuit (ASIC), a digital signal processor (DSP), a digital signal processing device (DSPD), a programmable logic device (PLD), a field programmable gate array (FPGA), a controller, a microcontroller, a microprocessor, or other electronic components, and is used to execute the reservoir determination method in the first embodiment above.

[0224] The memory 302 can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as a static random access memory (SRAM), an electrically erasable programmable read-only memory (EEPROM), an erasable programmable read-only memory (EPROM), a programmable read-only memory (PROM), a read-only memory (ROM), a magnetic memory, a flash memory, a magnetic disk, or an optical disc.

[0225] The multimedia component 303 can include a screen and an audio component. The screen can be a touch screen, and the audio component is used to output and / or input audio signals. For example, the audio component can include a microphone for receiving external audio signals. The received audio signals can be further stored in the memory or sent through the communication component. The audio component also includes at least one speaker for outputting audio signals.

[0226] The I / O interface 304 provides an interface between the processor 301 and other interface modules, and the other interface modules can be a keyboard, a mouse, buttons, etc. These buttons can be virtual buttons or physical buttons.

[0227] The communication component 305 is used for wired or wireless communication between the electronic device 300 and other devices. Wireless communication, such as Wi-Fi, Bluetooth, Near Field Communication (NFC), 2G, 3G or 4G, or a combination of one or more of them. Accordingly, the communication component 305 may include: a Wi-Fi module, a Bluetooth module, and an NFC module.

[0228] In summary, a method, apparatus, storage medium, and electronic device for determining a reservoir provided in this application establish a low-frequency model based on seismic data and logging data of a formation in a target area; perform inversion based on the low-frequency model to obtain the relative impedance body of the formation; update the low-frequency model according to the relative impedance body to obtain a target low-frequency model; perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data. A low-frequency model is established based on seismic data and logging data of a formation in a target area, and then inversion is performed on the low-frequency model to obtain the relative impedance body of the formation. The relative impedance body can reflect information such as the lithology and physical properties of the formation. Then, the low-frequency model is updated according to the relative impedance body, and after establishing a new low-frequency model, post-stack impedance inversion is performed on the new low-frequency model to obtain the longitudinal wave impedance data of the formation, so as to accurately determine the reservoir using the longitudinal wave impedance data.

[0229] In several embodiments provided in the embodiments of the present application, it should be understood that the disclosed systems and methods can also be implemented in other ways. The system and method embodiments described above are only illustrative.

[0230] It should be noted that in this article, the term "including", "comprising" or any other variant thereof is intended to cover a non-exclusive inclusion, so that a process, method, article or device including a series of elements not only includes those elements, but also includes other elements not explicitly listed, or further includes elements inherent to such process, method, article or device. Without further limitations, an element defined by the statement "including a..." does not exclude the existence of another identical element in the process, method, article or device including the element.

[0231] Although the disclosed embodiments of the present application are as above, the content described above is only an embodiment adopted for the convenience of understanding the present application and is not used to limit the present application. Any person skilled in the art within the technical field to which the present application belongs can make any modifications and changes in the form and details of the implementation without departing from the spirit and scope disclosed by the present application. However, the scope of patent protection of the present application shall still be subject to the scope defined by the appended claims.

Claims

1. A method for determining a reservoir, characterized in that, The method includes: Establishing a low-frequency model based on seismic data and logging data of the formation in the target area, including: establishing a time-depth relationship through well-seismic calibration based on the acquired logging data and seismic data; establishing a framework model of the clastic rock formation in the formation according to the time-depth relationship; determining the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the logging data; performing lateral interpolation on the framework model using the longitudinal wave impedance data to obtain the low-frequency impedance model of the clastic rock formation; determining the background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation based on the background longitudinal wave impedance value; determining the low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model; wherein, the seismic data includes seismic wavelet data, and establishing the time-depth relationship through well-seismic calibration based on the acquired logging data and seismic data includes: determining the reflection coefficient based on the acoustic wave data and density data of a single well; convolving the reflection coefficient and the seismic wavelet to obtain a synthetic seismic record; establishing the time-depth relationship based on the synthetic seismic record; Performing inversion based on the low-frequency model to obtain the relative impedance body of the formation; Updating the low-frequency model according to the relative impedance body to obtain the target low-frequency model, including: setting the value of the relative impedance body corresponding to the clastic rock formation to a null value, and retaining the negative value in the value of the relative impedance body corresponding to the carbonate rock formation to obtain a negative value impedance model; adding the negative value impedance model and the low-frequency model to obtain the target low-frequency model; Performing inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

2. The method according to claim 1, characterized in that Performing inversion based on the low-frequency model to obtain the relative impedance body of the formation, including: Performing constrained sparse pulse inversion on the low-frequency model based on the seismic data to obtain the relative impedance body of the formation.

3. The method according to claim 1, wherein The performing inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data, includes: Performing constrained sparse pulse inversion on the seismic data using the target low-frequency model to obtain the longitudinal wave impedance data of the formation; Determining the target longitudinal wave impedance data based on the longitudinal wave impedance data and the longitudinal wave impedance threshold; Determining the spatial position corresponding to the target longitudinal wave impedance data as the reservoir in the formation.

4. The method according to claim 3, characterized in that, The determining the target longitudinal wave impedance data based on the longitudinal wave impedance data and the longitudinal wave impedance threshold includes: Comparing the magnitudes of the longitudinal wave impedance data and the longitudinal wave impedance threshold; Determining the part of the longitudinal wave impedance data that is less than the longitudinal wave impedance threshold as the target longitudinal wave impedance data.

5. A determination device for a reservoir, characterized in that, The device includes: A low-frequency model establishment module, which is used to establish a low-frequency model according to the seismic data and well logging data of the formation in the target area, including: establishing a time-depth relationship based on the obtained well logging data and seismic data through well-seismic calibration; establishing a framework model of the clastic rock formation in the formation according to the time-depth relationship; determining the longitudinal wave impedance data and background longitudinal wave impedance data in the depth direction of the formation according to the well logging data; using the longitudinal wave impedance data to perform lateral interpolation on the framework model to obtain the low-frequency impedance model of the clastic rock formation; determining the background low-frequency longitudinal wave impedance model of the carbonate rock formation in the formation based on the background longitudinal wave impedance value; determining the low-frequency model based on the low-frequency impedance model and the background low-frequency longitudinal wave impedance model; wherein, the seismic data includes: seismic wavelet data, and the establishment of the time-depth relationship based on the obtained well logging data and seismic data through well-seismic calibration includes: determining the reflection coefficient based on the acoustic wave data and density data of a single well; convolving the reflection coefficient and the seismic wavelet to obtain a synthetic seismic record; establishing the time-depth relationship based on the synthetic seismic record; A relative impedance body acquisition module, which is used to perform inversion based on the low-frequency model to obtain the relative impedance body of the formation; A target low-frequency model acquisition module, which is used to update the low-frequency model according to the relative impedance body to obtain a target low-frequency model, including: setting the value of the relative impedance body corresponding to the clastic rock formation to a null value, and retaining the negative value in the value of the relative impedance body corresponding to the carbonate rock formation to obtain a negative impedance model; adding the negative impedance model and the low-frequency model to obtain the target low-frequency model; A reservoir determination module, which is used to perform inversion according to the target low-frequency model to determine the longitudinal wave impedance data of the formation, so as to determine the reservoir in the formation based on the longitudinal wave impedance data.

6. A storage medium, characterized in that, The computer program stored in the storage medium, when executed by one or more processors, is used to implement the reservoir determination method according to any one of claims 1-4.

7. An electronic device, characterized in that, It includes a memory and a processor, and a computer program is stored on the memory. When the computer program is executed by the processor, it executes the reservoir determination method according to any one of claims 1-4.

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