A method and device for evaluating the organic carbon content of a clayey hydrocarbon source rock containing a paste

Abstract

The present application relates to the technical field of new energy geothermal, in particular to a kind of organic carbon content logging evaluation method and device of argillaceous hydrocarbon source rock containing paste, method includes: the first acoustic travel time value is brought into the first logging curve correction model and is corrected processing, and then the second acoustic travel time value after correction processing is obtained;First argillaceous content is calculated based on the first measurement curve;Based on the first argillaceous content, the second acoustic travel time value and the first resistivity value, the organic carbon content corresponding to the measured hydrocarbon source rock layer is calculated;The present application adds logging curve correction model under the influence of the difference of hydrocarbon source rock maturity, then the model of high gamma curve response affected by the fine-grained deposition of argillaceous source rock is established, finally, the established calibration relationship is used to calculate the organic carbon content of the whole well section, realize the high-precision evaluation of hydrocarbon source rock organic matter abundance, provide practical and effective method for argillaceous hydrocarbon source rock logging evaluation.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of new energy geothermal, in particular to a method and device for evaluating organic carbon content of argillaceous source rock containing paste. BACKGROUND

[0002] Organic carbon content (TOC) is a main index reflecting the abundance of organic matter in source rock. The traditional method for obtaining TOC is to analyze core or rock sample experimentally, which is not suitable for continuous analysis of TOC of source rock in all exploration wells due to the limitation of core cost and experimental efficiency. Since source rock is heterogeneous, there is a large error in using the average value of a small amount of discrete TOC laboratory analysis.

[0003] The commonly used technical method in the petroleum industry is to obtain relatively continuous TOC through logging curves. Initially proposed by Exxon and Esso companies in 1979 based on statistical analysis of core data of actual well data, it is mainly realized based on the response difference of acoustic travel time and resistivity logging curves to shale layer. For complex lithology formations rich in gypsum, the acoustic travel time and resistivity response are affected by lithology, source rock maturity, oil and gas content, and compaction, so the actual application error of this technology is large, and it basically cannot be applied to source rock formations with large maturity difference, source rock containing gypsum, and deep thin interbedded source rock. SUMMARY

[0004] The present application relates to the technical field of new energy geothermal, in particular to a method and device for evaluating organic carbon content of argillaceous source rock containing paste.

[0005] In order to achieve the above-mentioned purpose, the embodiments of the present application provide the following technical solutions:

[0006] In one aspect, the present application provides a method for evaluating organic carbon content of argillaceous source rock containing paste, which comprises: constructing a logging curve correction model for the maturity difference of source rock, denoted as a first logging curve correction model; obtaining a first acoustic travel time value measured and inputting the first acoustic travel time value into the first logging curve correction model for correction processing, thereby obtaining a corrected first acoustic travel time value, denoted as a second acoustic travel time value; calculating a first argillaceous content based on a first measurement curve, the first measurement curve being a measured spontaneous potential curve or gamma curve; and calculating the organic carbon content corresponding to the measured source rock layer based on the first argillaceous content, the second acoustic travel time value and a first resistivity value.

[0007] Optionally, the first logging curve correction model is:

[0008] AC2=AC+(AC's depth-mudstone ACmax's depth) / formation thickness*(mudstone ACmax-mudstone ACmin);

[0009] In the formula, AC2 is the second acoustic time difference value, and AC is the first acoustic time difference value.

[0010] Optionally, the organic carbon content of the measured hydrocarbon source rock layer is calculated based on the first shale content, the second acoustic time difference value, and the first resistivity value, including:

[0011] If the first shale content is greater than 0.5, the second acoustic time difference value is less than the acoustic time difference baseline value, and the first resistivity value is less than the resistivity baseline value, the organic carbon content of the hydrocarbon source rock layer is calculated based on a first organic carbon content calculation formula, the first organic carbon content calculation formula being:

[0012] TOC=a*(0.02*(AC2-ACbaseline value)+log(RT / RTbaseline value))+b;

[0013] In the formula, Vsh is the first shale content, TOC is the organic carbon content, AC2 is the second acoustic time difference value, ACbaseline value is the acoustic time difference baseline value, RT is the first resistivity value, RTbaseline value is the resistivity baseline value, a and b are a fitting curve coefficient and a corresponding constant of TOC and an amplitude difference obtained through laboratory analysis, respectively.

[0014] Optionally, the organic carbon content of the measured hydrocarbon source rock layer is calculated based on the first shale content, the second acoustic time difference value, and the first resistivity value, including:

[0015] If the first shale content is greater than 0.5, the second acoustic time difference value is greater than the acoustic time difference baseline value, and the first resistivity value is greater than the resistivity baseline value, the organic carbon content of the hydrocarbon source rock layer is calculated based on a second organic carbon content calculation formula, the second organic carbon content calculation formula being:

[0016] TOC=carbon recovery coefficient*a*(0.02*(AC2-ACbaseline value)+log(RT / RTbaseline value))+b;

[0017] In the formula, TOC is the organic carbon content, AC2 is the second acoustic time difference value, ACbaseline value is the acoustic time difference baseline value, RT is the first resistivity value, RTbaseline value is the resistivity baseline value, a and b are a fitting curve coefficient and a corresponding constant of TOC and an amplitude difference obtained through laboratory analysis, respectively, and the carbon recovery coefficient is measured from historical test data.

[0018] In a second aspect, an embodiment of the present application provides a device for evaluating the organic carbon content of a clay-containing hydrocarbon source rock, the device comprising:

[0019] The first construction module is configured to construct a logging curve correction model for maturity difference of a hydrocarbon source rock, denoted as a first logging curve correction model.

[0020] The first acquisition module is configured to acquire a first interval transit time value measured and bring the first interval transit time value into the first logging curve correction model for correction processing, so as to obtain a first interval transit time value after correction processing, denoted as a second interval transit time value.

[0021] The first calculation module is configured to calculate a first shale content based on a first measurement curve, wherein the first measurement curve is a measured spontaneous potential curve or a gamma curve.

[0022] The second calculation module is configured to calculate an organic carbon content corresponding to a measured hydrocarbon source rock layer based on the first shale content, the second interval transit time value, and a first resistivity value.

[0023] In a third aspect, an embodiment of the present application provides a device for evaluating an organic carbon content of a shale hydrocarbon source rock containing clay, the device comprising a memory and a processor.

[0024] The memory is configured to store a computer program, and the processor is configured to execute the computer program to implement the steps of the method for evaluating the organic carbon content of the shale hydrocarbon source rock containing clay.

[0025] In a fourth aspect, an embodiment of the present application provides a medium having a computer program stored thereon, wherein the computer program is executed by a processor to implement the steps of the method for evaluating the organic carbon content of the shale hydrocarbon source rock containing clay.

[0026] The present application has the following beneficial effects:

[0027] The present application is to solve the problem that the fitting calculation formula has poor correlation and large calculation error when evaluating the organic matter of a hydrocarbon source rock due to the influence of clay and other lithologies, first, a logging curve correction model under the influence of maturity difference of a hydrocarbon source rock is added, second, a model of high gamma curve response affected by fine-grained deposition of a clay-containing source rock is established, and finally, the established calibration relationship is used to calculate the organic carbon content of the whole well section, so as to realize high-precision evaluation of the organic matter abundance of a hydrocarbon source rock, provide a practical and effective method for logging evaluation of a shale hydrocarbon source rock containing clay, and provide a basis for fine description of the spatial distribution of organic matter of a hydrocarbon source rock and prediction of a favorable oil and gas exploration prospect in oil and gas exploration.

[0028] Other features and advantages of the present application will be described in the following description, and some will become apparent from the description, or will be understood from the practice of the present application. The purpose and other advantages of the present application can be achieved and obtained by the structures specifically pointed out in the written description, claims, and drawings. BRIEF DESCRIPTION OF DRAWINGS

[0029] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following will briefly introduce the drawings needed to be used in the embodiments. It should be understood that the following drawings only show some of the embodiments of the present application, and therefore should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can also be obtained without creative labor on the basis of these drawings.

[0030] Figure 1 is a process schematic diagram of a method for evaluating the organic carbon content of a gypsum-containing argillaceous hydrocarbon source rock in the embodiments of the present application;

[0031] Figure 2 is a structural schematic diagram of an evaluation device for evaluating the organic carbon content of a gypsum-containing argillaceous hydrocarbon source rock in the embodiments of the present application;

[0032] Figure 3 is a structural schematic diagram of an evaluation equipment for evaluating the organic carbon content of a gypsum-containing argillaceous hydrocarbon source rock in the embodiments of the present application;

[0033] Figure 4 is a AC curve feature of He Tan 1 well in the embodiments of the present application.

[0034] Figure 5 is a comparison of TOC calculation results by two methods of He Tan 1 well in the Hehe Depression in the embodiments of the present application.

[0035] Figure 6 is a correlation graph of calculated TOC and measured TOC of He Tan 1 well in the embodiments of the present application. DETAILED DESCRIPTION

[0036] In order to make the purpose, technical solutions and advantages of the embodiments of the present application more clear, the following will combine the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are some of the embodiments of the present application, but not all the embodiments. The components of the embodiments of the present application described and shown in the drawings here can be arranged and designed in various different configurations. Therefore, the following detailed description of the embodiments of the present application provided in the drawings is not intended to limit the scope of the claimed present application, but only represents selected embodiments of the present application. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative labor belong to the scope of protection of the present application.

[0037] It should be noted that similar reference numerals or letters in the following figures indicate similar items; therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures. Furthermore, in the description of this invention, terms such as "first," "second," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0038] Example 1

[0039] like Figure 1 As shown in the figure, this embodiment provides a well logging evaluation method for organic carbon content in gypsum-bearing argillaceous source rocks, the method including steps S100, S200, S300 and S400.

[0040] Step S100: Construct a logging curve correction model for differences in the maturity of source rocks, denoted as the first logging curve correction model;

[0041] Step S200: Obtain the first acoustic transit time value obtained by measurement, and input the first acoustic transit time value into the first logging curve correction model for correction processing, thereby obtaining the first acoustic transit time value after correction processing, which is recorded as the second acoustic transit time value.

[0042] Step S300: Calculate the first mud content based on the first measurement curve, where the first measurement curve is the measured spontaneous potential curve or gamma curve;

[0043] Step S400: Based on the first mud content, the second acoustic transit time value and the first resistivity value, calculate the organic carbon content corresponding to the measured source rock layer.

[0044] The first logging curve correction model is as follows:

[0045] AC2 = AC + (depth of AC - depth of mudstone ACmax) / formation thickness * (mudstone ACmax - mudstone ACmin).

[0046] In the formula, AC2 is the second sound wave time difference value, and AC is the first sound wave time difference value.

[0047] Secondly, in step S400, based on the first mud content, the second acoustic transit time value, and the first resistivity value, the organic carbon content corresponding to the measured source rock layer is calculated, including:

[0048] Step S410: If the first mud content is greater than 0.5, the second acoustic transit time value is less than the acoustic transit time baseline value, and the first resistivity value is less than the resistivity baseline value, then the organic carbon content corresponding to the source rock layer is calculated based on the first organic carbon content calculation formula. The first organic carbon content calculation formula is:

[0049] TOC = a * (0.02 * (AC2 - AC baseline value) + log(RT / RT baseline value)) + b

[0050] In the formula, Vsh is the first shale content, TOC is the organic carbon content, AC2 is the second acoustic time difference value, AC baseline value is the acoustic time difference baseline value, RT is the first resistivity value, RT baseline value is the resistivity baseline value, and a and b are the fitting curve coefficient and corresponding constant of TOC and amplitude difference obtained through laboratory analysis.

[0051] In step S400, the organic carbon content corresponding to the measured hydrocarbon source rock is calculated based on the first shale content, the second acoustic time difference value, and the first resistivity value, including:

[0052] In step S420, if the first shale content is greater than 0.5, the second acoustic time difference value is greater than the acoustic time difference baseline value, and the first resistivity value is greater than the resistivity baseline value, the organic carbon content corresponding to the hydrocarbon source rock is calculated based on a second organic carbon content calculation formula, and the second organic carbon content calculation formula is:

[0053] TOC = a * (0.02 * (AC2 - AC baseline value) + log(RT / RT baseline value)) + b

[0054] In the formula, TOC is the organic carbon content, AC2 is the second acoustic time difference value, AC baseline value is the acoustic time difference baseline value, RT is the first resistivity value, RT baseline value is the resistivity baseline value, a and b are the fitting curve coefficient and corresponding constant of TOC and amplitude difference obtained through laboratory analysis, and the carbon recovery coefficient is measured from historical test data.

[0055] In the present embodiment, in order to solve the problem that the fitting calculation formula has poor correlation and large calculation error when evaluating the organic matter of hydrocarbon source rock by logging due to the influence of anhydrite and other lithologies, a logging curve correction model under the influence of the maturity difference of hydrocarbon source rock is first added, a model of high gamma curve response affected by fine-grained deposition of anhydrite-containing source rock is then established, and finally the established calibration relationship is used to calculate the organic carbon content of the entire well section, realizing high-precision evaluation of the organic matter abundance of hydrocarbon source rock, providing a practical and effective method for logging evaluation of anhydrite-containing shale hydrocarbon source rock, and providing a basis for fine description of the spatial distribution of hydrocarbon source rock organic matter and prediction of favorable oil and gas exploration prospects in oil and gas exploration.

[0056] Example 2

[0057] This embodiment is used to fully explain the principle of the entire technical solution:

[0058] The conventional evaluation method has large error because the acoustic travel time of the source rock with large maturity span from immaturity to high maturity varies greatly, the formation resistance of the source rock in the salinization environment varies greatly, and it is difficult to calculate the TOC value of the source rock in deep thin interbed through the logging curve.

[0059] Firstly, with the change of the maturity of the source rock, the acoustic travel time decreases from 300-600us / m to 100-200us / m, and the acoustic travel time value decreases obviously. According to the conventional source rock logging evaluation method, the top acoustic travel time baseline and the bottom difference are large.

[0060] Secondly, the gypsum is often developed in the source rock in the salinization environment, the acoustic travel time value of the gypsum mudstone is basically equivalent to that of the conventional mudstone, but the resistance response value is abnormally high, and the highest value is 5000 ohm.m, which is several orders of magnitude higher than that of the conventional mudstone.

[0061] Thirdly, the acoustic travel time value of the deep thin interbed is basically small, the resistance changes rapidly, and the resistance often presents a sharp spike.

[0062] The present application relates to the quantitative evaluation of the organic carbon content of the gypsum-rich argillaceous source rock by comprehensively applying the geochemical technology and logging information, and belongs to a comprehensive method of geophysical logging source rock quantitative evaluation different from the traditional evaluation technology in the petroleum geological exploration.

[0063] Firstly, the logging curve correction model under the influence of the difference of the maturity of the source rock is established, secondly, the model affected by the fine-grained deposition of the gypsum-containing source rock is established, and finally, the TOC of the source rock layer is calculated by using the established calibration relationship.

[0064] (1) Logging curve correction model of the difference of the maturity of the source rock:

[0065] With the change of the maturity of the source rock, the acoustic travel time decreases from 300-600us / m to 100-200us / m, and the acoustic travel time value decreases obviously by about 30-50%. According to the conventional source rock logging evaluation method, the top acoustic travel time baseline and the bottom difference are large, and the baseline of the acoustic travel time needs to be corrected.

[0066] The correction formula is:

[0067] AC correction = AC + (the depth of AC - the depth of mudstone ACmax) / formation thickness * (mudstone ACmax - mudstone ACmin)

[0068] (2) Calculation method of the gypsum-containing source rock / (3) High-precision identification calculation method of the source rock in deep thin interbed.

[0069] The conventional source rock logging evaluation calculation formula is:

[0070] TOC = -a * ((0.02 * (AC - AC baseline value) + log(RT / RT baseline value)) + b

[0071] TOC: organic carbon content; a: fitting curve coefficient; b: fitting curve constant; AC: acoustic time difference value

[0072] AC baseline value: acoustic time difference curve baseline value; RT: resistivity value; RT baseline value: resistivity curve baseline value

[0073] The logging evaluation of argillaceous shale source rock first distinguishes mudstone and sandstone formation through spontaneous potential curve or gamma curve, and the calculation formula is:

[0074] Shale content Vsh = (SP - SPmin) / (SPmax - SPmin).

[0075] In addition, use the IF statement to determine the lithology as non-hydrocarbon source rock if RT is greater than sandstone RTmax. Remove the argillaceous rock section.

[0076] The specific calculation formula is:

[0077] TOC = IF ((Vsh > 0.5, AC - AC baseline value < 0, TOC background value));

[0078] IF: Vsh > 0.5, AC - AC baseline value > 0, RT < RT baseline value, then the source rock is immature to low mature source rock, and the source rock is not large hydrocarbon generation or hydrocarbon expulsion, and the TOC content is generally high. The fitting curve coefficients a and b are determined by the TOC and amplitude difference of laboratory analysis, and the TOC content calculation formula is:

[0079] TOC = IF (Vsh > 0.5 and AC > AC baseline value and RT < RT baseline value, a * (0.02 * (AC - AC baseline value) + log(RT / RT baseline value)) + b, TOC background value);

[0080] IF: AC - AC baseline value > 0, RT > RT baseline value, then the source rock is mature source rock, and the TOC of laboratory analysis is generally low, so the correlation coefficient does not need to be too high. The fitting curve coefficients a and b are determined by the TOC and amplitude difference of laboratory analysis, and the TOC content calculation formula is:

[0081] TOC = IF (Vsh > 0.5 and AC > AC baseline value and RT > RT baseline value), carbon recovery coefficient * (0.02 * (AC - AC baseline value) + log(RT / RT baseline value)) + b;

[0082] (3) High-precision identification calculation method for deep thin interbedded source rock

[0083] The TOC content calculation formula of the deep sand shale thin layer hydrocarbon source rock is:

[0084] TOC=a*(0.02*(AC+(the depth of AC-the depth of mudstone ACmax) / stratum thickness*(mudstone ACmax-mudstone ACmin)-AC baseline value)+log(RT / RT baseline value))+b.

[0085] The method is applied to the evaluation of the deep-ultra deep thin layer gypsiferous argillaceous hydrocarbon source rock of the Linhe Formation in the Linhe Depression. The Linhe Formation in the Linhe Depression has a large sedimentary thickness, and the burial depth is about 3000-6500 m. At present, the drilling of well He Tan 1 in the vicinity of the depression area has only revealed the sedimentation of the second member of the Linhe Formation at a depth of more than 6000 m. The upper member of the first member of the Linhe Formation in the well He Tan 1 is brown and gray mudstone interbedded with light gray siltstone, and the gray mudstone of the Wuyuan Formation has a thickness of about 60 m, mainly medium-poor hydrocarbon source rock. The Linhe Formation is gray mudstone interbedded with light gray siltstone and fine sandstone, and oil and gas shows are observed. The gray mudstone has a thickness of 200.5 m, and the acoustic time difference value has a significant decreasing trend in the Linhe Formation Figure 4 .

[0086] The TOC value (TOC1 curve in the figure) calculated by the conventional hydrocarbon source rock logging evaluation is small, and the TOC is generally less than 0.7%. The TOC value calculated by the gypsiferous hydrocarbon source rock calculation method and the deep-ultra deep thin layer hydrocarbon source rock calculation method is between 0.39% and 1.35% (TOC2 curve in the figure). This is more consistent with the geological understanding. The first member of the Linhe Formation is dark mudstone, and the TOC value tested in the laboratory is between 0.53% and 1.3% (TOC circular scatter point in the figure). The TOC and S1+S2 content are medium, and the asphalt content A content is high. The hydrocarbon source rock organic matter abundance is higher than that of the brown mudstone of the Wuyuan Formation, and the calculated TOC is more consistent with the laboratory test results. See Figure 5 . Figure 5 Figure 5 Figure 6 .

[0087] The present application is suitable for gypsiferous hydrocarbon source rock formations in saline environments and formations with large maturity spans. It has a wide application prospect in the field of oil and gas exploration and resource evaluation, and provides support for predicting favorable oil and gas exploration areas.

[0088] The use of logging data to study and evaluate oil source rocks began in the 1970s abroad, and the work in this regard has also developed to a certain extent in China, but the evaluation of gypsiferous thin layer hydrocarbon source rock is basically not applicable.

[0089] The method of the present application provides a new method for calculating the organic carbon content of gypsiferous argillaceous hydrocarbon source rock. For the case where there is no obvious abnormality in acoustic time difference and resistivity logging response, it is the same as the commonly used method. The method is better in the gypsiferous mudstone and thin interbedded mudstone sections.

[0090] ​​Through the research and evaluation of oil source rocks in Linhe depression, the organic matter maturity of source rocks in Linhe Formation is in low-mature to mature stage in Nalinhu, Linhua and Xinghua areas, and in mature to high-mature stage in Guangming anticline. The maturity increases from south to north. The content of biomarker S / (S+R)-C29 and ββ-C29 is between 5% and 45%. The source rocks in Guyang Formation are in mature to high-mature stage. The content of biomarker S / (S+R)-C29 and ββ-C29 is between 20% and 55%. The maturity difference is large.

[0091] The method of the patent application solves the problem of poor correlation of the calculation model of the argillaceous source rock and thin interbedded mudstone under different maturity conditions. It is shown that the relatively continuous organic carbon content of the source rock can be calculated more accurately on the basis of the calibration of the geochemical analysis of the oil source rock core sample.

[0092] Embodiment 3

[0093] As shown in Figure 2 The embodiment provides a device for evaluating organic carbon content of argillaceous source rock by well logging, which comprises:

[0094] A first construction module 71 is configured to construct a well logging curve correction model for maturity difference of source rock, which is denoted as a first well logging curve correction model.

[0095] A first acquisition module 72 is configured to acquire a first acoustic travel time value measured and bring the first acoustic travel time value into the first well logging curve correction model for correction processing, so as to obtain a corrected first acoustic travel time value, which is denoted as a second acoustic travel time value.

[0096] A first calculation module 73 is configured to calculate a first shale content based on a first measurement curve, which is a measured spontaneous potential curve or gamma curve.

[0097] A second calculation module 74 is configured to calculate an organic carbon content corresponding to a measured source rock layer based on the first shale content, the second acoustic travel time value and a first resistivity value.

[0098] It should be noted that the specific manner in which the various modules execute operations in the device in the above embodiments has been described in detail in the embodiments related to the method, and will not be described in detail here.

[0099] Embodiment 4

[0100] Corresponding to the above method embodiments, the embodiments of the present disclosure also provide a device for evaluating organic carbon content of argillaceous source rock containing gypsum. The device for evaluating organic carbon content of argillaceous source rock containing gypsum described below can be correspondingly referred to the method for evaluating organic carbon content of argillaceous source rock containing gypsum described above.

[0101] Figure 3 is a block diagram of an electronic device 800 for evaluating organic carbon content of argillaceous source rock containing gypsum according to an exemplary embodiment. As shown in Figure 3 the electronic device 800 can include a processor 801, a memory 802. The electronic device 800 can also include one or more of a multimedia component 803, an I / O interface 804, and a communication component 805.

[0102] The processor 801 is configured to control overall operations of the electronic device 800 to complete all or part of the steps of the method for evaluating the organic carbon content of the clay shale containing paste hydrocarbon source rock described above. The memory 802 is configured to store various types of data to support the operation of the electronic device 800, which can include, for example, instructions for any application or method operating on the electronic device 800, and application-related data, such as contact data, transmitted and received messages, pictures, audio, video, and the like. The memory 802 can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk or optical disk. The multimedia component 803 can include a screen and an audio component. The screen can be, for example, a touch screen, and the audio component is configured to output and / or input audio signals. For example, the audio component can include a microphone configured to receive external audio signals. The received audio signals can be further stored in the memory 802 or transmitted through the communication component 805. The audio component also includes at least one speaker configured to output audio signals. The I / O interface 804 provides an interface between the processor 801 and other interface modules, which can be a keyboard, a mouse, a button, and the like. These buttons can be virtual buttons or physical buttons. The communication component 805 is configured to perform wired or wireless communication between the electronic device 800 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, so the corresponding communication component 805 can include a Wi-Fi module, a Bluetooth module, an NFC module.

[0103] In an example embodiment, the electronic device 800 can be implemented by one or more Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor or other electronic elements for executing the above-mentioned method for evaluating organic carbon content of shale source rock containing argillaceous mudstone.

[0104] In another example embodiment, a computer readable storage medium including program instructions is also provided, which when executed by a processor, implement the steps of the above-mentioned method for evaluating organic carbon content of shale source rock containing argillaceous mudstone. For example, the computer readable storage medium can be the above-mentioned memory 802 including program instructions, which can be executed by the processor 801 of the electronic device 800 to complete the above-mentioned method for evaluating organic carbon content of shale source rock containing argillaceous mudstone.

[0105] Embodiment 5

[0106] Corresponding to the above method embodiments, the embodiments of the present disclosure also provide a readable storage medium, which can be referred to the above-mentioned method for evaluating organic carbon content of shale source rock containing argillaceous mudstone.

[0107] A readable storage medium, on which a computer program is stored, the computer program, when executed by a processor, implements the steps of the above-mentioned method for evaluating organic carbon content of shale source rock containing argillaceous mudstone.

[0108] The readable storage medium can be specifically a U disk, a mobile hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk or an optical disk, and various readable storage media that can store program codes.

[0109] The above only describes the preferred embodiments of the present disclosure and is not used to limit the present disclosure. For those skilled in the art, the present disclosure can have various modifications and changes. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present disclosure shall be included in the protection scope of the present disclosure.

Claims

1. A method for evaluating the organic carbon content of a shaly source rock containing paste, characterized in that, The method includes: A well logging curve correction model for differences in the maturity of source rocks is constructed, denoted as the first well logging curve correction model; The first acoustic transit time value obtained by measurement is acquired, and the first acoustic transit time value is substituted into the first logging curve correction model for correction processing to obtain the first acoustic transit time value after correction processing, which is recorded as the second acoustic transit time value. The first mud content is calculated based on the first measurement curve, which is the measured spontaneous potential curve or gamma curve. Based on the first mud content, the second acoustic transit time value, and the first resistivity value, the organic carbon content corresponding to the measured hydrocarbon source rock layer is calculated. The first logging curve correction model is as follows: AC2 = AC + (depth of AC - depth of mudstone ACmax) / formation thickness * (mudstone ACmax - mudstone ACmin). In the formula, AC2 is the second sound wave time difference value, and AC is the first sound wave time difference value; Based on the first mud content, the second acoustic transit time value, and the first resistivity value, the organic carbon content corresponding to the measured source rock layer is calculated, including: If the first mud content is greater than 0.5, the second acoustic transit time value is greater than the acoustic transit time baseline value, and the first resistivity value is greater than the resistivity baseline value, then the organic carbon content corresponding to the source rock layer is calculated based on the second organic carbon content calculation formula, which is: TOC = Carbon Recovery Factor * a * (0.02 * (AC² - AC Baseline Value) + log(RT / RT Baseline Value)) + b; In the formula, TOC is the organic carbon content, AC2 is the second acoustic time difference value, AC baseline value is the acoustic time difference baseline value, RT is the first resistivity value, RT baseline value is the resistivity baseline value, a and b are the fitting curve coefficients and corresponding constants of TOC and amplitude difference obtained by laboratory analysis, respectively, and the carbon recovery coefficient is measured from historical experimental data.

2. The method for evaluating the organic carbon content of a shaly source rock containing paste according to claim 1, characterized in that, Based on the first mud content, the second acoustic transit time value, and the first resistivity value, the organic carbon content corresponding to the measured source rock layer is calculated, including: If the first mud content is greater than 0.5, the second acoustic transit time value is less than the acoustic transit time baseline value, and the first resistivity value is less than the resistivity baseline value, then the organic carbon content corresponding to the source rock layer is calculated based on the first organic carbon content calculation formula, which is: TOC = a * (0.02 * (AC² - AC baseline value) + log(RT / RT baseline value)) + b; In the formula, Vsh is the first mud content, TOC is the organic carbon content, AC2 is the second acoustic time difference value, AC baseline value is the acoustic time difference baseline value, RT is the first resistivity value, RT baseline value is the resistivity baseline value, and a and b are the fitting curve coefficients and corresponding constants of TOC and amplitude difference obtained by laboratory analysis, respectively.

3. A device for evaluating the organic carbon content of a shaly source rock containing a paste, characterized in that, The device includes: The first construction module is used to construct a logging curve correction model for differences in the maturity of source rocks, denoted as the first logging curve correction model; The first acquisition module is used to acquire the first acoustic transit time value obtained by measurement, and to input the first acoustic transit time value into the first logging curve correction model for correction processing, thereby obtaining the corrected first acoustic transit time value, which is recorded as the second acoustic transit time value. The first calculation module is used to calculate the first mud content based on the first measurement curve, wherein the first measurement curve is the measured spontaneous potential curve or gamma curve. The second calculation module is used to calculate the organic carbon content corresponding to the measured source rock layer based on the first mud content, the second acoustic transit time value and the first resistivity value. The first logging curve correction model is as follows: AC2 = AC + (depth of AC - depth of mudstone ACmax) / formation thickness * (mudstone ACmax - mudstone ACmin). In the formula, AC2 is the second sound wave time difference value, and AC is the first sound wave time difference value; The second calculation module is specifically used for: If the first mud content is greater than 0.5, the second acoustic transit time value is greater than the acoustic transit time baseline value, and the first resistivity value is greater than the resistivity baseline value, then the organic carbon content corresponding to the source rock layer is calculated based on the second organic carbon content calculation formula, which is: TOC = Carbon Recovery Factor * a * (0.02 * (AC² - AC Baseline Value) + log(RT / RT Baseline Value)) + b; In the formula, TOC is the organic carbon content, AC2 is the second acoustic time difference value, AC baseline value is the acoustic time difference baseline value, RT is the first resistivity value, RT baseline value is the resistivity baseline value, a and b are the fitting curve coefficients and corresponding constants of TOC and amplitude difference obtained by laboratory analysis, respectively, and the carbon recovery coefficient is measured from historical experimental data.

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