Method, device, medium and electronic device for calculating vitrinite reflectance of hydrocarbon source rock

Abstract

The application discloses a method and device for calculating vitrinite reflectance of a hydrocarbon source rock, a medium and an electronic device. The method comprises the following steps: obtaining a vitrinite reflectance measurement value by analyzing a hydrocarbon source rock formation core; establishing a multiple regression relationship by performing depth homing, standardizing a density logging curve, and combining the vitrinite reflectance measurement value; obtaining a time horizon of a top interface of the hydrocarbon source rock and a bottom interface of the hydrocarbon source rock by performing seismic reflection interpretation; calculating an intermediate vertical depth horizon based on the time horizon; obtaining a density three-dimensional data body by standardizing a sonic time difference curve and a standardized density curve; obtaining a bulk density horizon by combining the time horizon and the density three-dimensional data body; and calculating the vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizon and the bulk density horizon. The technical scheme provided by the application can improve the accuracy of calculating the vitrinite reflectance.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oil exploration, and particularly relates to a method and device for calculating vitrinite reflectivity of source rock, a medium and an electronic device. BACKGROUND

[0002] Source rock refers to rock capable of generating oil and gas flow with industrial value, and is one of the key factors for controlling whether an oil and gas reservoir can be formed in a certain sedimentary basin. During the exploration and evaluation stage of an oil and gas basin, accurate evaluation of source rock is an important basis for locking a favorable exploration target. In recent years, tight oil and gas has shown great exploration and development potential, and tight oil and gas is adjacent to or located in source rock, and evaluation of source rock is also an important content of tight oil and gas evaluation. Source rock evaluation mainly includes three aspects: organic matter abundance, organic matter type and maturity of organic matter of source rock. The maturity of organic matter of source rock is an important indicator for measuring the actual hydrocarbon generation capacity of source rock, and is an important basis for evaluating the hydrocarbon generation amount and resource prospect of a region or a certain source rock system. Vitrinite reflectivity is the most commonly used maturity indicator for representing the maturity of source rock. Therefore, continuous and accurate determination of the vitrinite reflectivity of source rock has important practical significance for oil and gas exploration and tight oil evaluation of an oil and gas basin.

[0003] At present, from the research status at home and abroad, the vitrinite reflectivity of source rock is mainly determined based on the analysis and test of source rock cores, and on this basis, mathematical methods are applied to grid the analysis and test data of planar discrete distribution and limited quantity to obtain a planar contour map of the vitrinite reflectivity of source rock. However, this idea only obtains the planar distribution characteristics of the vitrinite reflectivity of source rock by mathematical operation on the analysis and test data of known points, without considering the changes in the vitrinite reflectivity caused by factors such as changes in the burial depth of source rock. The vitrinite reflectivity of source rock between wells is only calculated by mathematical methods, and cannot truly reflect the changes in the vitrinite reflectivity. Moreover, it is difficult to reflect the actual vitrinite reflectivity of source rock by using analysis and test data at certain depths for source rock with large thickness. Therefore, the existing method has certain limitations and cannot give accurate and geologically meaningful calculation values of the vitrinite reflectivity of source rock. Therefore, the application provides a method for calculating the vitrinite reflectivity of source rock to improve the accuracy of calculating the vitrinite reflectivity. SUMMARY

[0004] Embodiments of the application provide a method, device, medium and electronic device for calculating the vitrinite reflectivity of source rock, which can improve the accuracy of calculating the vitrinite reflectivity.

[0005] Other characteristics and advantages of the application will become apparent from the following detailed description, or will be learned by practice of the application.

[0006] According to a first aspect of the embodiments of the present application, a method for calculating vitrinite reflectance of a hydrocarbon source rock is provided, and the method is characterized in that the method comprises: obtaining vitrinite reflectance measurement values corresponding to hydrocarbon source rock formation cores of different well points by analyzing the hydrocarbon source rock formation cores; establishing a multiple regression relationship by depth homing of the hydrocarbon source rock formation cores, standardizing density logging curves of the hydrocarbon source rock formation cores, and combining the vitrinite reflectance measurement values corresponding to the hydrocarbon source rock formation cores of the different well points; interpreting seismic reflections of a top interface of a hydrocarbon source rock and a bottom interface of the hydrocarbon source rock after horizon calibration of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock according to three-dimensional seismic data, so as to obtain time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock; obtaining vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock in a manner of time-depth conversion based on the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, so as to calculate intermediate vertical depth horizons corresponding to each calculation unit; obtaining a density three-dimensional data body of the hydrocarbon source rock by density inversion of a standardized acoustic traveltime curve and a standardized density curve; obtaining volume density horizons corresponding to each calculation unit in combination with the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and the density three-dimensional data body; and calculating vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizons, and the volume density horizons.

[0007] In some embodiments of the present application, based on the foregoing scheme, the calculation of the intermediate vertical depth horizons corresponding to each calculation unit comprises: calculating thicknesses of each calculation unit according to the vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and in combination with a preset number of calculation units; and calculating the intermediate vertical depth horizons of the calculation units according to the vertical depth horizons of the top interface of the hydrocarbon source rock and the thicknesses of the calculation units.

[0008] In some embodiments of the present application, based on the foregoing scheme, the obtaining of the volume density horizons corresponding to each calculation unit comprises: calculating time thicknesses of each calculation unit according to the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and in combination with a preset number of calculation units; calculating time horizons of the top interface and the bottom interface corresponding to each calculation unit according to the time horizons of the top interface of the hydrocarbon source rock and the time thicknesses, so as to determine average densities corresponding to each calculation unit, and further taking the average densities corresponding to each calculation unit as the volume density horizons corresponding to each calculation unit.

[0009] In some embodiments of the present application, based on the foregoing scheme, after calculating the vitrinite reflectance corresponding to each calculation unit, the method further comprises: calculating the average measured value of the vitrinite reflectance measured value corresponding to any one calculation unit according to the vitrinite reflectance measured value; calculating the absolute error and the relative error corresponding to the any one calculation unit according to the average measured value and the vitrinite reflectance corresponding to the any one calculation unit, so as to correct the vitrinite reflectance corresponding to the any one calculation unit according to the absolute error and the relative error.

[0010] In some embodiments of the present application, based on the foregoing scheme, the correction of the vitrinite reflectance corresponding to the any one calculation unit comprises: if the absolute error is greater than a preset absolute error and the relative error is greater than a preset relative error, constructing a vitrinite reflectance fitting curve according to the average measured value and the vitrinite reflectance corresponding to the any one calculation unit, so as to correct the vitrinite reflectance corresponding to the any one calculation unit according to the vitrinite reflectance fitting curve.

[0011] In some embodiments of the present application, based on the foregoing scheme, the interpretation density of the interpretation of the seismic reflection of the top interface and the bottom interface of the source rock is 1x1.

[0012] In some embodiments of the present application, based on the foregoing scheme, the vitrinite reflectance corresponding to each calculation unit is calculated by the following formula:

[0013] R on =a×H ρn +b×H dn +c

[0014] Wherein, R on is the vitrinite reflectance corresponding to each calculation unit, H ρn is the volume density horizon, H dn is the intermediate vertical depth horizon, and a, b and c are characteristic coefficients of the source rock formation.

[0015] Compared with the prior art, the present application has at least the following beneficial effects:

[0016] The present application obtains the vitrinite reflectance measured value corresponding to the source rock formation core of different well points by making the source rock formation core into samples for analysis and testing, and measuring the vitrinite reflectance of each sample by using a microphotometer.

[0017] The application of three-dimensional seismic data, on the basis of the horizon calibration of the top interface and the bottom interface of the hydrocarbon source rock, the seismic reflection of the top interface and the bottom interface of the hydrocarbon source rock is interpreted, so as to obtain the time horizon of the top interface and the bottom interface of the hydrocarbon source rock. Then, the time depth conversion of the time horizon of the top interface and the bottom interface of the hydrocarbon source rock is carried out by establishing a velocity field, so as to obtain the vertical depth horizon of the top interface and the bottom interface of the hydrocarbon source rock.

[0018] According to the obtained vertical depth horizon of the top interface and the bottom interface of the hydrocarbon source rock and the preset number of calculation units, the thickness of each calculation unit is calculated to obtain the corresponding intermediate vertical depth horizon of each calculation unit. The density inversion is carried out on the standardized acoustic time difference curve and the standardized density curve to obtain the density three-dimensional data body of the hydrocarbon source rock. Then, according to the obtained time horizon of the top interface and the bottom interface of the hydrocarbon source rock and the preset number of calculation units, the corresponding bulk density horizon of each calculation unit is obtained, so as to calculate the corresponding vitrinite reflectance of each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizon and the bulk density horizon.

[0019] Based on the above method, the method for calculating the vitrinite reflectance of the hydrocarbon source rock provided by the application can improve the accuracy of calculating the vitrinite reflectance.

[0020] According to a second aspect of the embodiments of the present application, a device for calculating vitrinite reflectance of a hydrocarbon source rock is provided, and the device comprises: a measuring unit configured to obtain vitrinite reflectance measurement values corresponding to hydrocarbon source rock formation cores of different well points by analyzing the hydrocarbon source rock formation cores; a first data processing unit configured to establish a multiple regression relationship by depth homing of the hydrocarbon source rock formation cores, standardizing density logging curves of the hydrocarbon source rock formation cores, and combining the vitrinite reflectance measurement values corresponding to the hydrocarbon source rock formation cores of the different well points; a second data processing unit configured to obtain time horizons of a top interface of the hydrocarbon source rock and a bottom interface of the hydrocarbon source rock by interpreting seismic reflections of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock according to three-dimensional seismic data and after horizon calibration of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock; a data conversion unit configured to obtain vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock by combining the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and by using a time-depth conversion method, so as to calculate intermediate vertical depth horizons corresponding to each calculation unit; a third data processing unit configured to obtain a density three-dimensional data volume of the hydrocarbon source rock by density inversion of a standardized acoustic traveltime curve and a standardized density curve; a fourth data processing unit configured to obtain volume density horizons corresponding to each calculation unit by combining the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and the density three-dimensional data volume; and a fifth data processing unit configured to calculate vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizons, and the volume density horizons.

[0021] According to a third aspect of the embodiments of the present application, a computer readable storage medium is provided, and the computer readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement operations performed by the method.

[0022] According to a fourth aspect of the embodiments of the present application, an electronic device is provided, and the electronic device comprises one or more processors and one or more memories, and the one or more memories store at least one program code, and the at least one program code is loaded and executed by the one or more processors to implement operations performed by the method.

[0023] The advantages of the above-mentioned second aspect to fourth aspect and each embodiment of the first aspect are as described above, and will not be repeated here.

[0024] It should be understood that the above general description and the following detailed description are only exemplary and explanatory, and cannot limit the present application. BRIEF DESCRIPTION OF DRAWINGS

[0025] The drawings incorporated in and forming a part of the specification, illustrate preferred embodiments of the present application and, together with the description, serve to explain the principles of the present application. It is apparent that the drawing in the following description is only some embodiments of the present application, and other drawings can be obtained by those of ordinary skill in the art without creative labor, based on these drawings. In the drawings:

[0026] Figure 1 A flow chart of a method for calculating the vitrinite reflectance of a hydrocarbon source rock in the embodiments of the present application is shown;

[0027] Figure 2 A schematic diagram of the division of a calculation unit and the intermediate vertical depth in the embodiments of the present application is shown;

[0028] Figure 3 A schematic diagram of the intermediate vertical depth horizon in the calculation unit 1 in the embodiments of the present application is shown;

[0029] Figure 4 A schematic diagram of the volume density horizon in the calculation unit 1 in the embodiments of the present application is shown;

[0030] Figure 5 A schematic diagram of the amplitude tuning body frequency spectrum slice in the embodiments of the present application is shown;

[0031] Figure 6 A vitrinite reflectance fitting curve in the embodiments of the present application is shown;

[0032] Figure 7 A planar distribution diagram of the corrected vitrinite reflectance in the embodiments of the present application is shown;

[0033] Figure 8 A structural schematic diagram of a device for calculating the vitrinite reflectance of a hydrocarbon source rock in the embodiments of the present application is shown;

[0034] Figure 9 A structural schematic diagram of an electronic device in the embodiments of the present application is shown. DETAILED DESCRIPTION

[0035] The technical solutions in the embodiments of the present application will be described clearly and completely below in combination with the drawings in the embodiments of the present application. Obviously, the described embodiments are only some of the embodiments of the present application, but not all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative labor are within the scope of protection of the present application.

[0036] Moreover, the described features, structures, or characteristics can be combined in any suitable manner in one or more embodiments. In the following description, numerous specific details are provided to give a thorough understanding of embodiments of the application. One skilled in the relevant art will recognize, however, that the application can be practiced without one or more of the specific details, or with other methods, components, devices, steps, etc. In other instances, well-known structures, devices, implementations, or operations are not shown or described in detail to avoid obscuring aspects of the application.

[0037] The block diagrams shown in the drawings are functional entities, which do not necessarily have to correspond to physically independent entities. That is, these functional entities can be implemented in the form of software, or in one or more hardware modules or integrated circuits, or in different network and / or processor devices and / or microcontroller devices.

[0038] The flowcharts shown in the drawings are only illustrative, and do not necessarily include all contents and operations / steps, nor are they necessarily executed in the order described. For example, some operations / steps can be further decomposed, and some operations / steps can be combined or partially combined, so the actual execution order can be changed according to actual conditions.

[0039] Next, the application will be described in detail:

[0040] Figure 1 A flowchart of a method for calculating vitrinite reflectance of a hydrocarbon source rock in an embodiment of the application is shown. The method for calculating vitrinite reflectance of a hydrocarbon source rock can be executed by a device with a calculation processing function, such as a device for calculating vitrinite reflectance of a hydrocarbon source rock. Referring to Figure 1 As shown, the method for calculating vitrinite reflectance of a hydrocarbon source rock includes at least steps 110 to 170, which are described in detail as follows:

[0041] In step 110, vitrinite reflectance measurement values corresponding to hydrocarbon source rock formation cores of different well points are obtained by analyzing the hydrocarbon source rock formation cores.

[0042] In step 120, a multiple regression relationship is established by depth homing the hydrocarbon source rock formation cores, standardizing the density logging curves of the hydrocarbon source rock formation cores, and combining the vitrinite reflectance measurement values corresponding to the hydrocarbon source rock formation cores of the different well points.

[0043] In step 130, after horizon calibration is performed on the top boundary surface of a hydrocarbon source rock and the bottom boundary surface of a hydrocarbon source rock based on three-dimensional seismic data, the seismic reflection of the top boundary surface of a hydrocarbon source rock and the bottom boundary surface of a hydrocarbon source rock is interpreted, so that the time horizon of the top boundary surface of a hydrocarbon source rock and the bottom boundary surface of a hydrocarbon source rock is obtained.

[0044] At step 140, based on the time horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, and in combination with the time-depth conversion mode, the vertical depth horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock is obtained, so as to calculate the intermediate vertical depth horizon corresponding to each calculation unit.

[0045] At step 150, the density 3D data volume of the hydrocarbon source rock is obtained by carrying out density inversion on the normalized acoustic travel time curve and the normalized density curve.

[0046] At step 160, in combination with the time horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, and the density 3D data volume, the bulk density horizon corresponding to each calculation unit is obtained.

[0047] At step 170, according to the multiple regression relationship, the intermediate vertical depth horizon, and the bulk density horizon, the vitrinite reflectance corresponding to each calculation unit is calculated.

[0048] In the present application, according to the research needs, all the hydrocarbon source rock formation cores in the research area are sampled at fixed depths as intervals and are made into samples for analysis and testing. The hydrocarbon source rock formation cores are analyzed by a microphotometer to obtain the vitrinite reflectance measurement values corresponding to the hydrocarbon source rock formation cores of different well points.

[0049] On the basis of step 110, the hydrocarbon source rock formation cores are depth-matched, and the density logging curves of the hydrocarbon source rock formation cores are standardized. According to the logging data, the vertical depth horizon corresponding to each hydrocarbon source rock formation core and the response value of the standardized density logging curve are counted. A multiple regression relationship of vitrinite reflectance, vertical depth horizon, and bulk density of the hydrocarbon source rock formation core is established by using a multiple regression method. It should be noted that the depth-matching of the hydrocarbon source rock formation cores refers to matching the hydrocarbon source rock formation cores with the depth of the logging data. The vertical depth horizon refers to the vertical depth from the ground surface to a certain point underground.

[0050] Further, in an embodiment of the present application, the multiple regression relationship is R o =a×ρ+b×TVD+c, wherein a, b, and c are characteristic coefficients of the hydrocarbon source rock formation, ρ is the bulk density of the hydrocarbon source rock formation core, TVD is the vertical depth horizon, and R o is the vitrinite reflectance.

[0051] Then, according to the three-dimensional seismic data, and after the horizon calibration of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, the seismic reflection of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock is interpreted, so as to obtain the time horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock. Based on the time horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, a velocity field is established to perform time-depth conversion on the time horizon of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock. For example, the obtained time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock are H tt and H tb respectively. After the time-depth conversion, the obtained vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock are H dt and H db respectively. The velocity field refers to a physical field composed of the velocity at each point and each time in the three-dimensional space, and the seismic reflection refers to the connecting line of the extreme values of the phase of each trace on the seismic record.

[0052] Referring to Figure 2 , a calculation unit division and an intermediate vertical depth diagram in the embodiment of the present application are shown. After obtaining the vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock, the hydrocarbon source rock formation can be divided into calculation units according to the actual thickness of the hydrocarbon source rock and the research needs. For example, the hydrocarbon source rock formation is divided into n calculation units, and the thickness T of each calculation unit is obtained by subtracting the depth horizon H dt of the top interface of the hydrocarbon source rock from the depth horizon H db of the bottom interface of the hydrocarbon source rock to obtain the total thickness of the hydrocarbon source rock, and then dividing the total thickness of the hydrocarbon source rock by the preset number n of calculation units. Referring to Figure 3 , a calculation unit 1 intermediate vertical depth horizon diagram in the embodiment of the present application is shown. After obtaining the thickness T of each calculation unit, the calculation unit thickness is divided by 2 to obtain T / 2, and T / 2 is added to the depth horizon of the top surface of the hydrocarbon source rock to obtain the intermediate vertical depth horizon H d1 of the calculation unit 1. The intermediate depth horizon H d1 of the calculation unit 1 is added to T to obtain the intermediate vertical depth horizon H d2 of the calculation unit 2. In this way, the intermediate vertical depth horizon H dn of the last calculation unit is obtained.

[0053] Further, in one embodiment of the present application, the interpretation density of the seismic reflection of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock is 1x1.

[0054] On the basis of the standardization of the acoustic travel time curve and the density curve, density inversion is carried out to obtain the density three-dimensional data body of the hydrocarbon source rock, and then according to the time horizon H tt of the top interface of the hydrocarbon source rock and the time horizon H tb of the bottom interface of the hydrocarbon source rock obtained in step 130, the vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock are obtained.This allows us to obtain the volume density layers corresponding to each computational unit.

[0055] Furthermore, in one embodiment of this application, obtaining the volume density strata corresponding to each computing unit may include the following steps: calculating the time thickness of each computing unit based on the time strata of the top and bottom interfaces of the source rock and in combination with a preset number of computing units; calculating the time strata of the top and bottom interfaces corresponding to each computing unit based on the time strata of the top interface of the source rock and the time thickness, thereby determining the planar distribution strata corresponding to each computing unit, and then using the planar distribution strata corresponding to each computing unit as the volume density strata corresponding to each computing unit.

[0056] Specifically, refer to Figure 4 This diagram illustrates the volume density strata of calculation unit 1 in an embodiment of this application. The time strata H at the base of the source rock are used. tb Subtract the time horizon H of the top interface of the source rock tt Obtain the time thickness T of the source rock t Then use the source rock time and thickness T t Divide by the preset number of computing units n to obtain the time thickness T of each computing unit. te Time thickness T te Time horizon H at the top interface of the source rock tt The summation yields the time level H at the bottom interface of computational unit 1. t1 Time thickness T te Time layer H at the bottom interface of computing unit 1 t1 The summation yields the bottom time level H of computational unit 2. t2 This process continues until the bottom time level H of the last computational unit is obtained. tn Based on this, the planar distribution layer of the average density of each computational unit is extracted using the top and bottom interface time layers as constraints, and is used as the volume density layer H of each computational unit. ρn .

[0057] The density inversion mentioned above refers to the technique of calculating the volumetric density of underground geological bodies based on seismic data and well logging data using principal component analysis algorithms or geostatistical principles.

[0058] Based on the multivariate regression equations, intermediate vertical depth layers, and volume density layers obtained above, the vitrinite reflectance corresponding to each calculation unit is calculated.

[0059] Furthermore, in one embodiment of this application, the vitrinite reflectance corresponding to each computing unit is calculated using the following formula:

[0060] Ron = a x H ρn + b x H dn + c

[0061] wherein R on is the vitrinite reflectance of each calculation unit, H ρn is the bulk density horizon, H dn is the intermediate vertical depth horizon, and a, b, and c are characteristic coefficients of the source rock formation.

[0062] Meanwhile, referring to Figure 5 , a schematic diagram of amplitude tuning body spectrum slicing in the embodiments of the present application is shown. In Figure 5 , the planar distribution of the vitrinite reflectance of the source rock formation can be clearly known.

[0063] In the present application, after the vitrinite reflectance of each calculation unit is calculated, the method for calculating the vitrinite reflectance of the source rock can further include steps 210 to 220:

[0064] Step 210: according to the measured value of the vitrinite reflectance, the average measured value of the measured value of the vitrinite reflectance of any one calculation unit is calculated.

[0065] Step 220: according to the average measured value and the vitrinite reflectance of any one calculation unit, the absolute error and the relative error of any one calculation unit are calculated, so that the vitrinite reflectance of any one calculation unit is corrected according to the absolute error and the relative error.

[0066] Specifically, taking any one calculation unit as an example, according to the measured value of the vitrinite reflectance obtained in step 110, the calculation unit thickness at the location of the coring well is divided, and the measured value of the vitrinite reflectance is plotted into a histogram according to the division result. The average value of the measured value of the vitrinite reflectance in the area with the highest frequency of the measured value of the vitrinite reflectance in the histogram is taken, so that the average value of the measured value of the vitrinite reflectance is taken as the measured value of the vitrinite reflectance R onc1 of the calculation unit at the well point. R onc1 is compared with the calculated value R on1 at the well point obtained according to the method for calculating the vitrinite reflectance of the source rock, and the absolute error ε n1 and the relative error δ n1 of the calculation unit at the well point are calculated, so that the vitrinite reflectance of any one calculation unit calculated according to the method for calculating the vitrinite reflectance of the source rock is corrected according to the absolute error and the relative error. Wherein ε n1 = R on1 - R onc1 , δ n1 = εn1 / R onc1 ×100%。

[0067] Further, in one embodiment of the present application, if the absolute error is greater than the preset absolute error and the relative error is greater than the preset relative error, a vitrinite reflectance fitting curve is constructed according to the average measured value and the vitrinite reflectance corresponding to the arbitrary calculation unit, so as to correct the vitrinite reflectance corresponding to the arbitrary calculation unit according to the vitrinite reflectance fitting curve.

[0068] For example, the absolute error calculated by the arbitrary calculation unit is 0.008%, and the relative error is 1.63%. Since the absolute error 0.008% of the current calculation unit is greater than the preset absolute error, and the relative error 1.63% is greater than the preset relative error, it is necessary to correct the vitrinite reflectance of the arbitrary calculation unit according to the vitrinite reflectance measured value R onci and the vitrinite reflectance R oni calculated by the method for calculating vitrinite reflectance of source rock. onci The scatter plot of R oni and R on is made, and the vitrinite reflectance fitting curve is constructed. Referring to Figure 6 , the vitrinite reflectance fitting curve in the embodiment of the present application is shown. The vitrinite reflectance calculation result R on is corrected according to the fitting vitrinite reflectance fitting curve to obtain the final result R onf . The vitrinite reflectance fitting curve can be y=0.9883x+0.0008. 0.9883 and 0.0008 are the fitting coefficients of the vitrinite reflectance fitting curve. Based on this, the calculation formula of the corrected vitrinite reflectance in the present application is R onf =0.9883×R on +0.0008. Based on this, Figure 7 the planar distribution map of the corrected vitrinite reflectance in the embodiment of the present application is shown.

[0069] Based on the same inventive concept, the present application also provides a device for calculating vitrinite reflectance of source rock. Referring to Figure 8, the device for calculating vitrinite reflectance of hydrocarbon source rock in the embodiment of the present application is shown. The device for calculating vitrinite reflectance of hydrocarbon source rock 800 comprises: a measuring unit 801 configured to obtain vitrinite reflectance measurement values corresponding to hydrocarbon source rock formation cores of different well points by analyzing the hydrocarbon source rock formation cores; a first data processing unit 802 configured to establish a multiple regression relationship by depth homing the hydrocarbon source rock formation cores, standardizing density logging curves of the hydrocarbon source rock formation cores, and combining the vitrinite reflectance measurement values corresponding to the hydrocarbon source rock formation cores of the different well points; a second data processing unit 803 configured to obtain time horizons of a top interface of a hydrocarbon source rock and a bottom interface of the hydrocarbon source rock after horizon calibration of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock based on three-dimensional seismic data and interpretation of seismic reflections of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock; a data conversion unit 804 configured to obtain vertical depth horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock based on the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and in a time-depth conversion manner, so as to calculate intermediate vertical depth horizons corresponding to each calculation unit; a third data processing unit 805 configured to obtain a density three-dimensional data body of the hydrocarbon source rock by density inversion of a standardized acoustic traveltime curve and a standardized density curve; a fourth data processing unit 806 configured to obtain volume density horizons corresponding to each calculation unit by combining the time horizons of the top interface of the hydrocarbon source rock and the bottom interface of the hydrocarbon source rock and the density three-dimensional data body; and a fifth data processing unit 807 configured to calculate vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizons, and the volume density horizons.

[0070] For details not disclosed in the device embodiment of the present application, refer to the above-mentioned method embodiments of the present application.

[0071] Based on the same inventive concept, the present application can also provide a computer readable storage medium, characterized in that the computer readable storage medium stores at least one program code, the at least one program code is loaded and executed by a processor to implement the operations performed by the method

[0072] Based on the same inventive concept, the present application further provides an electronic device, which is described with reference to Figure 9 , Figure 9 The structure of the electronic device in the embodiment of the present application is shown.

[0073] The electronic device comprises one or more memories 904, one or more processors 902, and at least one computer program (program code) stored in the memory 904 and executable on the processor 902, and the processor 902 executes the computer program to implement the method as described above.

[0074] wherein, in Figure 9 The bus architecture, represented by the bus 900, can include any number of interconnected buses and bridges, the bus 900 linking together various circuits including the processor 902, represented by one or more processors, and the memory 904, represented by the memory. The bus 900 can also link together various other circuits, such as peripheral devices, voltage stabilizers and power management circuits, which are well-known in the art, and thus, not further described herein. The bus interface 905 provides an interface between the bus 900 and the receiver 901 and the transmitter 903. The receiver 901 and the transmitter 903 can be the same element, i.e., a transceiver, providing a means for communicating with various other apparatuses over a transmission medium. The processor 902 is responsible for managing the bus 900 and general processing, while the memory 904 can be used for storing data used by the processor 902 in executing operations.

[0075] The functions described herein can be implemented in hardware, software executed by a processor, firmware, or any combination thereof. If implemented in software executed by a processor, the functions can be stored on or transferred over as one or more instructions or code on a computer-readable medium. Other examples and implementations are within the scope and spirit of the disclosure and appended claims. For example, due to the nature of software, functions described above can be implemented using software executed by a processor, hardware, firmware, hardwiring, or combinations of any of these. Features implementing functions can also be physically located at various positions, including being distributed such that portions of functions are implemented at different physical locations. Also, as technology evolves, the underlying functions and logic can be implemented by equivalent equivalents.

[0076] In several embodiments provided in the present application, it should be understood that the disclosed technology can be implemented in other ways. Among them, the above-mentioned device embodiments are only schematic, for example, the division of the units can be a logical function division, and actual implementation can have another division mode, for example, a plurality of units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point, the coupling or direct coupling or communication connection between the displayed or discussed each other can be through some interface, indirect coupling or communication connection between units or modules, which can be electrical or other forms.

[0077] The units described as separate components can or can not be physically separated, and the components of the control device can or can not be physical units, that is, they can be located in one place, or they can be distributed on multiple units. Part or all of the units can be selected according to actual needs to achieve the purpose of the embodiment scheme.

[0078] The integrated unit, if implemented in the form of a software function unit and sold or used as an independent product, can be stored in a computer readable storage medium. Based on such understanding, the technical solutions of the present application essentially or say the part that contributes to the prior art or the whole or part of the technical solutions can be embodied in the form of a software product. The computer software product is stored in a storage medium, including a plurality of instructions to make a computer device (which can be a personal computer, a server or a network device, etc.) execute all or part of the steps of the method described in various embodiments of the present application. The aforementioned storage medium includes: a U disk, a read-only memory (ROM, Read-Only Memory), a random access memory (RAM, Random Access Memory), a mobile hard disk, a magnetic disk or an optical disk and various media that can store program codes.

[0079] The above only describes the embodiments of the present application and is not used to limit the present application. For those skilled in the art, the present application can have various changes and modifications. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included in the scope of claims of the present application.

Claims

1. A method for calculating vitrinite reflectance of a hydrocarbon source rock, the method comprising: The method comprises: obtaining vitrinite reflectance measurement values corresponding to source rock formation cores of different well points by analyzing the source rock formation cores; establishing a multiple regression relationship by depth homing of the source rock formation cores, standardizing the density logging curves of the source rock formation cores, and combining the vitrinite reflectance measurement values corresponding to the source rock formation cores of the different well points; obtaining time horizons of the source rock top interface and the source rock bottom interface by interpreting seismic reflections of the source rock top interface and the source rock bottom interface according to three-dimensional seismic data and after horizon calibration of the source rock top interface and the source rock bottom interface; obtaining vertical depth horizons of the source rock top interface and the source rock bottom interface based on the time horizons of the source rock top interface and the source rock bottom interface and in a manner of time-depth conversion, thereby calculating intermediate vertical depth horizons corresponding to each calculation unit; obtaining a density three-dimensional data body of the source rock by density inversion of the standardized acoustic traveltime curves and the standardized density curves; obtaining volume density horizons corresponding to each calculation unit in combination with the time horizons of the source rock top interface and the source rock bottom interface and the density three-dimensional data body; calculating vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizons, and the volume density horizons.

2. The method of claim 1, wherein, The calculation of the intermediate vertical depth horizons corresponding to each calculation unit comprises: calculating thicknesses of each calculation unit according to the vertical depth horizons of the source rock top interface and the source rock bottom interface and in combination with a preset number of calculation units; calculating intermediate vertical depth horizons of each calculation unit according to the vertical depth horizons of the source rock top interface and the thicknesses of the calculation units.

3. The method of claim 1, wherein, The obtaining of the volume density horizons corresponding to each calculation unit comprises: calculating time thicknesses of each calculation unit according to the time horizons of the source rock top interface and the source rock bottom interface and in combination with a preset number of calculation units; calculating time horizons of the top interface and the bottom interface corresponding to each calculation unit according to the time horizons of the source rock top interface and the time thicknesses, thereby determining average densities corresponding to each calculation unit, and further taking the average densities corresponding to each calculation unit as the volume density horizons corresponding to each calculation unit.

4. The method of claim 1, wherein, After the calculation of the vitrinite reflectance corresponding to each calculation unit, the method further comprises: calculating an average measurement value of the vitrinite reflectance measurement value corresponding to any one calculation unit according to the vitrinite reflectance measurement values; calculating absolute error and relative error corresponding to the any one calculation unit according to the average measurement value and the vitrinite reflectance corresponding to the any one calculation unit, thereby correcting the vitrinite reflectance corresponding to the any one calculation unit according to the absolute error and the relative error.

5. The method of claim 4, wherein, The correction of the vitrinite reflectance corresponding to the any one calculation unit comprises: If the absolute error is greater than a preset absolute error and the relative error is greater than a preset relative error, a vitrinite reflectance fitting curve is constructed according to the average vitrinite reflectance measurement value and the vitrinite reflectance corresponding to the arbitrary calculation unit, and the vitrinite reflectance corresponding to the arbitrary calculation unit is corrected according to the vitrinite reflectance fitting curve.

6. The method of claim 1, wherein, The interpretation density of the seismic reflection of the top interface and the bottom interface of the source rock is 1*1.

7. The method of claim 1, wherein, The vitrinite reflectance corresponding to each calculation unit is calculated by the following formula: R on = a x H ρn + b x H dn + c Wherein, R on is the vitrinite reflectance corresponding to each calculation unit, H ρn is the volume density horizon, H dn is the intermediate vertical depth horizon, a, b, c are characteristic coefficients of the source rock formation.

8. A device for calculating the reflectance of vitrinite in hydrocarbon source rocks, characterized in that, The device comprises: A measurement unit is configured to obtain the vitrinite reflectance measurement value corresponding to the source rock formation core of different well points by analyzing the source rock formation core; A first data processing unit is configured to establish a multiple regression relationship by depth homing of the source rock formation core, standardizing the density logging curve of the source rock formation core, and combining the vitrinite reflectance measurement value corresponding to the source rock formation core of different well points; A second data processing unit is configured to interpret the seismic reflection of the top interface and the bottom interface of the source rock according to the three-dimensional seismic data after the horizon calibration of the top interface and the bottom interface of the source rock, so as to obtain the time horizon of the top interface and the bottom interface of the source rock; A data conversion unit is configured to obtain the vertical depth horizon of the top interface and the bottom interface of the source rock based on the time horizon of the top interface and the bottom interface of the source rock and by combining the time-depth conversion mode, so as to calculate the intermediate vertical depth horizon corresponding to each calculation unit; A third data processing unit is configured to obtain the density three-dimensional data body of the source rock by density inversion of the standardized acoustic time difference curve and the standardized density curve; A fourth data processing unit is configured to obtain the volume density horizon corresponding to each calculation unit by combining the time horizon of the top interface and the bottom interface of the source rock and the density three-dimensional data body; A fifth data processing unit is configured to calculate the vitrinite reflectance corresponding to each calculation unit according to the multiple regression relationship, the intermediate vertical depth horizon, and the volume density horizon.

9. A computer-readable storage medium, characterized in that, The computer readable storage medium stores at least one program code, and the at least one program code is loaded and executed by the processor to realize the operations performed by the method of any one of claims 1 to 7.

10. An electronic device, comprising: The electronic device comprises one or more processors and one or more memories, and the one or more memories store at least one program code, and the at least one program code is loaded and executed by the one or more processors to realize the operations performed by the method of any one of claims 1 to 7.

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