Shale pore type identification method and device, electronic equipment and storage medium

Abstract

The invention discloses a shale pore type identification method and device, electronic equipment and a storage medium. The method comprises the steps that the organic carbon content of a target interval of a research area is obtained through calculation according to logging curve sound waves, resistivity and gamma; according to the logging curve sound waves, the porosity of the target interval of the research area is obtained through calculation; determining the organic porosity by utilizing the content and the surface porosity of the organic carbon, the percentage of conversion of the organic carbon into hydrocarbon in the shale, the carbon-containing index, the apparent density of the shale and the skeleton density of the organic matter; and based on the organic carbon content and the porosity, constructing an organic porosity estimation plate, and based on the organic porosity estimation plate and the organic porosity, carrying out semi-quantitative identification on the pore type of the high-maturity shale. According to the technical scheme, estimation of the organic porosity in the shale can be simply and efficiently achieved, then semi-quantitative evaluation is conducted on shale oil and gas favorable reservoir pore type characteristics, and key guidance is provided for shale oil resource evaluation and exploration production services.

Description

Technical Field

[0001] The present invention relates to the technical fields of oil and gas geology and well logging, and in particular to a shale pore type identification method, device, electronic equipment and storage medium. Background Art

[0002] Shale oil is an unconventional natural gas reservoir with integrated source and reservoir or close source and reservoir. Its pore type directly affects oil and gas storage. Shale oil is mostly stored in organic pores. Therefore, it is necessary to establish an effective organic pore prediction model to accurately evaluate the scale of shale oil resources and provide key parameters for shale oil resource evaluation and exploration and development.

[0003] At present, most of the research on shale organic pores in China is focused on the high-maturity and over-maturity stages of shale, with the purpose of serving shale gas evaluation and exploration and production. The main research methods are experimental testing and observation methods, such as temperature and pressure simulation, helium testing, CT scanning, nuclear magnetic resonance, etc. Modica et al. believed that organic pores in shale are the main storage space for shale oil, and established a quantitative prediction model for organic porosity—the PhiK model—using the volumetric method; Guo Qiulin et al. established the relationship between organic porosity and kerogen type and organic maturity, and then quantitatively calculated the organic porosity based on this relationship, laying the foundation for calculating shale oil resources; Wu Songtao et al. combined temperature and pressure simulation with nano-CT three-dimensional characterization technology to qualitatively characterize the development characteristics of organic pores in mudstone; Chen et al. proposed an evaluation method for correcting shale organic pores using rock pyrolysis instrument (Rock-Eval) test data. In addition, domestic and foreign scholars have borrowed methods from porous material pore research to determine and characterize shale pores. The methods mainly include image analysis represented by field emission scanning electron microscopy (FE-SEM) and scanning imaging technology (CT), and medium injection methods represented by gas adsorption (N2, CO2), high-pressure mercury injection, nuclear magnetic resonance, helium porosity, etc.

[0004] Different methods have made great breakthroughs in the accuracy of characterizing porosity and pore structure characteristics. There are relatively few methods for quantitative characterization of organic and inorganic pore types, and they are still in an exploratory research stage. Most methods mainly make qualitative observations on pore types, which are costly and have certain limitations in the results. At the same time, the sedimentary environment in shale development areas in my country is very complex. According to conventional research, there is no simple linear relationship between the porosity of organic-rich shale and the abundance of organic matter, which increases the difficulty of predicting the pore type in shale oil reservoirs. Summary of the invention

[0005] The present invention provides a shale pore type identification method, device, electronic equipment and storage medium, which can simply and efficiently realize the estimation of organic porosity in shale, and then conduct semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs, providing key guidance for shale oil resource evaluation and exploration and production services.

[0006] According to one aspect of the present invention, a method for identifying shale pore types is provided, the method comprising:

[0007] Based on the sonic wave, resistivity and gamma of the logging curve, the organic carbon content of the target layer in the study area is calculated;

[0008] According to the acoustic wave of the well logging curve, the porosity of the target layer section in the study area is calculated;

[0009] Determine the organic porosity using the organic carbon content and surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter;

[0010] Based on the organic carbon content and porosity, an organic pore estimation chart is constructed, and based on the organic porosity estimation chart and organic porosity, semi-quantitative identification of the pore type of highly mature shale is performed.

[0011] According to another aspect of the present invention, a shale pore type identification device is provided, the device comprising:

[0012] The organic carbon content calculation module is used to calculate the organic carbon content of the target layer in the study area based on the acoustic wave, resistivity and gamma of the logging curve;

[0013] A porosity calculation module, used to calculate the porosity of the target layer section in the study area according to the acoustic wave of the logging curve;

[0014] An organic porosity determination module is used to determine the organic porosity using the organic carbon content and the surface ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon content index, the apparent density of the shale, and the skeleton density of the organic matter;

[0015] The high-maturity shale pore type identification module is used to construct an organic pore estimation map based on the organic carbon content and porosity, and to semi-quantitatively identify the high-maturity shale pore type based on the organic porosity estimation map and organic porosity.

[0016] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0017] at least one processor; and

[0018] a memory communicatively connected to the at least one processor; wherein,

[0019] The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute a shale pore type identification method described in any embodiment of the present invention.

[0020] According to another aspect of the present invention, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement a shale pore type identification method described in any embodiment of the present invention when executed.

[0021] The technical solution of the embodiment of the present invention calculates the organic carbon content of the target layer section in the study area according to the acoustic wave, resistivity and gamma of the logging curve, and calculates the porosity of the target layer section in the study area according to the acoustic wave of the logging curve, and determines the organic porosity by using the organic carbon content and face ratio, the percentage of organic carbon in shale converted into hydrocarbons, the carbon index, the apparent density of shale, and the skeleton density of organic matter, and then constructs an organic pore estimation plate based on the organic carbon content and porosity, and semi-quantitatively identifies the pore type of highly mature shale based on the organic porosity estimation plate and the organic porosity. This technical solution can simply and efficiently realize the estimation of organic porosity in shale, and then semi-quantitatively evaluate the pore type characteristics of favorable shale oil and gas reservoirs, and provide key guidance for shale oil resource evaluation and exploration and production services.

[0022] It should be understood that the contents described in this section are not intended to identify the key or important features of the embodiments of the present invention, nor are they intended to limit the scope of the present invention. Other features of the present invention will become easily understood through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0024] Figure 1 is a flow chart of a shale pore type identification method provided according to Embodiment 1 of the present invention;

[0025] Figure 2 The correlation between the resistivity of a known well and the organic carbon content of a core provided in Example 1 of the present application is as follows;

[0026] Figure 3 is the correlation relationship between the known well gamma and the core organic carbon content provided in Example 1 of the present application;

[0027] Figure 4 The correlation between the acoustic time difference of a known well and the organic carbon content of a core provided in Example 1 of the present application is as follows;

[0028] Figure 5 It is the comparison result between the logging TOC and the core TOC provided in Example 1 of the present application;

[0029] Figure 6 is the correlation relationship between the acoustic wave and the core porosity provided in Example 1 of the present application;

[0030] Figure 7 It is the comparison result between the logging porosity and the core porosity provided in Example 1 of the present application;

[0031] Figure 8 is a schematic diagram of an organic pore estimation chart provided in Example 1 of the present application;

[0032] Fig. 9 This is the actual application result of the semi-qualitative quantitative version of the pore type of organic shale provided in Example 1 of the present application;

[0033] Fig.10 is a structural schematic diagram of a shale pore type identification device provided according to Embodiment 2 of the present invention;

[0034] Fig.11 It is a structural schematic diagram of an electronic device for implementing a shale pore type identification method according to an embodiment of the present invention. DETAILED DESCRIPTION

[0035] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0036] It should be noted that the term "target" and the like in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any of their variations are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0037] Embodiment 1

[0038] Figure 1 This is a flow chart of a shale pore type identification method provided according to the first embodiment of the present invention. This embodiment is applicable to the semi-quantitative identification of high-mature shale pore types. The method can be performed by a shale pore type identification device. The shale pore type identification device can be implemented in the form of hardware and / or software. The shale pore type identification device can be configured in an electronic device. Figure 1 As shown, the method includes:

[0039] S110. Calculate the organic carbon content of the target layer in the study area based on the acoustic wave, resistivity and gamma of the logging curve.

[0040] In this scheme, the target layer section of the study area can be a marine organic-rich shale layer section. For example, the target layer section can be the Jurassic and Cambrian organic-rich shales in the central Sichuan area, and the process is mainly based on the Jurassic lacustrine shale in the central Sichuan area.

[0041] Among them, the content of organic matter in water, expressed as the amount of carbon, the main element in organic matter, is called organic carbon.

[0042] In this scheme, the well logging curve acoustic wave P, which is commonly used to distinguish the lithology of clastic rocks, can be selected from the parameters of known wells. AC , resistivity RT and gamma GR.

[0043] Furthermore, Figure 2 is the correlation between the resistivity of a known well and the organic carbon content of a core provided in Example 1 of the present application, Figure 3 is the correlation relationship between the known well gamma and the core organic carbon content provided in Example 1 of the present application; Figure 4 This is the correlation between the acoustic time difference of a known well and the organic carbon content of the core provided in Example 1 of the present application. Figure 2 , Figure 3 and Figure 4As shown, by analyzing the acoustic wave P of the logging curve AC The linear relationship between the resistivity RT and gamma GR and the organic carbon content TOC was studied, and it was found that the correlation between the individual logging curve and the organic carbon content TOC was very poor, or even non-existent. AC , resistivity RT and gamma GR are used to calculate the organic carbon content TOC in the target layer.

[0044] Optionally, the organic carbon content of the target layer in the study area can be calculated based on the acoustic wave, resistivity and gamma of the well logging curve, including:

[0045] The organic carbon content was calculated using the following formula;

[0046] TOC=A*P AC +B*log10 (RT) +C*GR+D;

[0047] Among them, TOC represents organic carbon content, P AC represents the acoustic wave of the logging curve, RT represents resistivity, GR represents gamma, and A, B, C, and D represent constants respectively.

[0048] In this embodiment, the acoustic wave P of the well logging curve can be used to AC , resistivity RT and gamma GR, and the TOC content of the target layer was calculated using the multivariate regression fitting method.

[0049] For example, starting from the known well parameters, the well logging curve acoustic wave P of the organic-rich shale is selected. AC , resistivity RT and gamma GR, and use the multivariate regression fitting method to calculate the organic carbon content TOC of the target layer:

[0050] TOC=0.059*P AC -0.154*log10 (RT) -0.086*GR-20314.

[0051] By calculating the organic carbon content, it is possible to make a semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs based on the organic carbon content, providing key guidance for shale oil resource evaluation and exploration and production services.

[0052] Optionally, the method further includes:

[0053] The organic carbon content is compared to pre-determined core test results.

[0054] The core test result may refer to the core organic carbon content TOC.

[0055] In this embodiment, the TOC content of well logging can be compared with the TOC content of the core, so as to verify the reliability of the TOC content of well logging.

[0056] Specifically, Figure 5 This is the comparison result between the logging TOC and the core TOC provided in Example 1 of the present application. Figure 5 As shown in the figure, the TOC results calculated by logging are very consistent with the measured core TOC results, with a correlation coefficient of 0.78.

[0057] The accuracy of the organic carbon content can be improved by comparing it with pre-determined core test results.

[0058] S120, calculating the porosity of the target layer in the study area according to the acoustic wave of the logging curve.

[0059] Among them, porosity refers to the ratio of the sum of the volumes of all pore spaces in a rock sample to the volume of the rock sample.

[0060] In this scheme, the porosity POR can be evaluated based on the acoustic wave of the logging curve and the application of the empirical relationship method.

[0061] Furthermore, Figure 6 is the correlation relationship between the acoustic wave and the core porosity provided in Example 1 of the present application, such as Figure 6 As shown, the core acoustic wave P of the known well is established AC The calculation relationship between it and the porosity POR.

[0062] Optionally, the porosity of the target layer in the study area is calculated based on the acoustic wave of the well logging curve, including:

[0063] The porosity was calculated using the following formula;

[0064] POR=A*P AC +B;

[0065] Where POR represents porosity, P AC represents the acoustic wave of the logging curve, and A and B represent constants respectively.

[0066] In this embodiment, the porosity POR is evaluated based on the well logging curve acoustic wave, and the porosity POR of the known well core acoustic wave POR is established. AC The calculation relationship between porosity POR:

[0067] POR=0.18*P AC -7.7912.

[0068] Optionally, the method further includes:

[0069] The porosity is compared to pre-determined core test results.

[0070] The core test result may be the core porosity POR.

[0071] In this scheme, the well logging porosity POR and the core porosity POR can be compared to verify the reliability of the well logging porosity POR.

[0072] In this embodiment, Figure 7 is the comparison result between the logging porosity and the core porosity provided in Example 1 of the present application, such as Figure 7 As shown in the figure, the well logging POR is compared with the core measured POR, and the two are in good agreement, with a correlation coefficient of 0.95.

[0073] The accuracy of the porosity can be improved by comparing it to pre-determined core test results.

[0074] S130. Determine the organic porosity using the organic carbon content and surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon content index, the apparent density of the shale, and the skeleton density of the organic matter.

[0075] Among them, organic porosity is an important component of shale reservoir space and has strong heterogeneity, which hinders the correct understanding and evaluation of shale reservoir quality. Its essence is affected by the type of organic microscopic components and their pore evolution during hydrocarbon generation.

[0076] In this embodiment, the face ratio may refer to the percentage of the gap area to the total area of ​​the observation field.

[0077] In this solution, the surface porosity, the percentage of organic carbon in shale converted into hydrocarbons, the carbon content index, the apparent density of shale, and the skeleton density of organic matter can be obtained based on the logging data.

[0078] Specifically, the organic carbon content, the surface area ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter can be combined and calculated to determine the organic porosity.

[0079] Optionally, the organic porosity is determined using the organic carbon content and surface ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter, including:

[0080] The surface ratio is calculated based on the predetermined organic pore volume and the apparent volume of organic matter, wherein the apparent volume of organic matter is used to characterize the overall volume of organic matter;

[0081] The organic carbon content and the surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter are combined and calculated to determine the organic porosity.

[0082] In this example, the organic pore volume is used to characterize the volume of pores.

[0083] In this scheme, the organic pore volume and the apparent volume of organic matter can be combined to calculate the surface area ratio.

[0084] By calculating the organic porosity, we can make a semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs, providing key guidance for shale oil resource evaluation and exploration and production services.

[0085] Optionally, the surface ratio is calculated based on the predetermined organic pore volume and organic matter apparent volume, including:

[0086] The surface ratio is calculated by dividing the organic pore volume and the apparent volume of organic matter.

[0087] Specifically, the calculation formula for the surface ratio S of organic matter in shale is:

[0088]

[0089] Wherein, V1 represents the organic pore volume and V2 represents the apparent volume of organic matter.

[0090] In this scheme, the calculation formula for the apparent volume of organic matter V2 is:

[0091] V2=V3+V1=V3+V2*S;

[0092] Among them, V3 represents the volume of organic matter.

[0093] Thus we can get:

[0094]

[0095] By calculating the surface ratio, the organic porosity can be determined based on the surface ratio, and then a semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs can be made, providing key guidance for shale oil resource evaluation and exploration and production services.

[0096] Optionally, the organic carbon content and the surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter are combined and calculated to determine the organic porosity, including:

[0097] The organic porosity was calculated using the following formula;

[0098]

[0099] Among them, POR Organic represents organic porosity, S represents surface porosity, TOC represents organic carbon content, Tr represents the percentage of organic carbon in shale converted into hydrocarbons, Cs represents carbon content index, ρ rock represents the apparent density of shale, ρ organic Represents the skeleton density of organic matter.

[0100] In this scheme, the percentage of organic carbon in shale converted into hydrocarbons, i.e., the conversion rate, is calculated as follows;

[0101]

[0102] Among them, Tr represents the percentage of organic carbon in shale converted into hydrocarbons, which is a function of the maturity of organic matter in shale, Ro represents the maturity of organic matter, and a and b represent constants.

[0103] The volume of organic matter in shale is:

[0104]

[0105] Where V4 represents the shale volume, Cs represents the carbon content index, 0.85, ρ rock Indicates the apparent density of shale, g / cm 3 , ρ organic Indicates the skeleton density of organic matter, g / cm 3 .

[0106] The calculation formula of organic porosity in shale is:

[0107]

[0108] Thus we get:

[0109]

[0110] In this scheme, in the high-overmature thermal evolution stage, the density of the organic skeleton in the organic-rich shale is about 1.5g / cm3, and the carbon index is about 0.85. The apparent density of the rock is 2.45-2.65g / cm3. Within this range, the calculated volume change of organic matter in the rock is small. In order to compare the effect of the change of organic matter surface ratio S on the organic porosity in the shale, the apparent density of the shale is taken as a constant value of 2.51g / cm3. The maturity is 1.3%. The calculation formula of organic porosity is:

[0111]

[0112] By calculating the organic porosity, we can make a semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs, providing key guidance for shale oil resource evaluation and exploration and production services.

[0113] S140. Based on the organic carbon content and porosity, an organic pore estimation chart is constructed, and based on the organic porosity estimation chart and the organic porosity, semi-quantitative identification of the pore type of the highly mature shale is performed.

[0114] In this scheme, since shale oil is mostly stored in organic pores, it is necessary to establish a simple, time-saving and efficient organic pore prediction method to accurately evaluate the scale of shale oil resources and provide key parameters for shale oil resource evaluation and exploration and development. Specifically, the organic porosity in shale can be simply and efficiently estimated from the perspective of mass balance based on organic carbon content and porosity.

[0115] Specifically, Figure 8 is a schematic diagram of an organic pore estimation chart provided in Example 1 of the present application, such as Figure 8 As shown in the figure, an organic pore estimation chart is constructed based on organic carbon content and porosity. When crude oil is cracked to form natural gas dominated by methane, the pyrolysis asphalt formed in organic-rich shale is half the mass of crude oil. From the perspective of mass balance, when S = 50%. It can be approximately considered that the organic pores produced by the TOC corresponding to this line are the maximum value of the organic porosity formed by crude oil cracking, without considering the contribution of inorganic pores to the total porosity. The straight line of S = 50% represents that the average surface porosity of organic matter in shale reaches 50%, and the porosity above this line is contributed by inorganic pores. The straight line of S = 30% represents that the average surface porosity of organic matter is 30% without considering inorganic pores. If inorganic pores are developed in the samples below this line, the average surface porosity of organic matter must be lower than 30%.

[0116] Furthermore, by calculating the logging TOC and porosity, and investing in the TOC-POR plate, the purpose of estimating the organic porosity in shale is achieved, and then the pore type characteristics of favorable shale oil and gas reservoirs are semi-quantitatively evaluated, providing key guidance for shale oil resource evaluation and exploration and production services.

[0117] In this program, Fig. 9 This is the actual application result of the semi-qualitative quantitative version of the pore type of organic shale provided in Example 1 of this application, such as Fig. 9 As shown, Sichuan dwarf The TOC content of Cambrian shales is generally low, but the porosity is high, basically above S = 50%, and some sample points are distributed near the straight line, indicating that the pores of lacustrine shales in the central Sichuan region are well developed. Moreover, inorganic pores in shale have a significant contribution to the total porosity. Similarly, the Cambrian marine shales have generally well developed organic pores, and the contribution of organic pores in shales to the total porosity is mainly distributed in the organic pore porosity between 10% and 50%. Among them, the porosity of some sample points of Cambrian shales is distributed below the S = 20% straight line, indicating that the overall development of both organic pores and inorganic mineral pores in shale is poor. According to the above results, the storage space of shale oil and gas in the central Sichuan region is mainly dominated by inorganic pores, and the organic pores in the Cambrian organic-rich shales provide important space for shale oil and gas storage, while the shales below the S = 20% straight line have poor development of both organic pores and inorganic pores, and the reservoir is not developed, so it is difficult for shale gas to make a breakthrough.

[0118] Semi-quantitative identification of pore types in highly mature shales can provide key guidance for shale oil resource evaluation and exploration and production services in my country's highly mature shales.

[0119] The technical solution of the embodiment of the present invention calculates the organic carbon content of the target layer section in the study area according to the acoustic wave, resistivity and gamma of the logging curve, and calculates the porosity of the target layer section in the study area according to the acoustic wave of the logging curve, and determines the organic porosity by using the organic carbon content and face ratio, the percentage of organic carbon in shale converted into hydrocarbons, the carbon index, the apparent density of shale, and the skeleton density of organic matter, and then constructs an organic pore estimation plate based on the organic carbon content and porosity, and semi-quantitatively identifies the pore type of highly mature shale based on the organic porosity estimation plate and the organic porosity. By executing this technical solution, the estimation of organic porosity in shale can be realized simply and efficiently, and then the semi-quantitative evaluation of the pore type characteristics of favorable shale oil and gas reservoirs can be performed, providing key guidance for shale oil resource evaluation and exploration and production services.

[0120] Embodiment 2

[0121] Fig.10 Schematic diagram of the structure of a shale pore type identification device provided according to the second embodiment of the present invention. Fig.10 As shown, the device comprises:

[0122] The organic carbon content calculation module 1010 is used to calculate the organic carbon content of the target layer section in the study area according to the acoustic wave, resistivity and gamma of the well logging curve;

[0123] A porosity calculation module 1020 is used to calculate the porosity of the target layer section in the study area according to the acoustic wave of the well logging curve;

[0124] An organic porosity determination module 1030 is used to determine the organic porosity using the organic carbon content and the surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon content index, the apparent density of the shale, and the skeleton density of the organic matter;

[0125] The high-maturity shale pore type identification module 1040 is used to construct an organic pore estimation chart based on the organic carbon content and porosity, and to semi-quantitatively identify the high-maturity shale pore type based on the organic porosity estimation chart and the organic porosity.

[0126] Optionally, the organic carbon content calculation module 1010 is specifically used for:

[0127] The organic carbon content was calculated using the following formula;

[0128] TOC=A*P AC +B*log10 (RT) +C*GR+D;

[0129] Among them, TOC represents organic carbon content, P AC represents the acoustic wave of the logging curve, RT represents resistivity, GR represents gamma, and A, B, C, and D represent constants respectively.

[0130] Optionally, the porosity calculation module 1020 is specifically used for:

[0131] The porosity was calculated using the following formula;

[0132] POR=A*P AC +B;

[0133] Where POR represents porosity, P AC represents the acoustic wave of the logging curve, and A and B represent constants respectively.

[0134] Optionally, the organic porosity determination module 1030 includes:

[0135] A surface ratio calculation unit, used to calculate the surface ratio according to the predetermined organic pore volume and organic matter apparent volume; wherein the organic matter apparent volume is used to characterize the overall volume of organic matter;

[0136] The organic pore determination unit is used to perform combined calculations on the organic carbon content and surface porosity, the percentage of organic carbon in shale converted into hydrocarbons, the carbon index, the apparent density of shale, and the skeleton density of organic matter to determine the organic porosity.

[0137] Optional, face rate calculation unit, specifically used for:

[0138] The surface ratio is calculated by dividing the organic pore volume and the apparent volume of organic matter.

[0139] Optionally, an organic pore determination unit is specifically used for:

[0140] The organic porosity was calculated using the following formula;

[0141]

[0142] Among them, POR Organic represents organic porosity, S represents surface porosity, TOC represents organic carbon content, Tr represents the percentage of organic carbon in shale converted into hydrocarbons, Cs represents carbon content index, ρ rock represents the apparent density of shale, ρ organic Represents the skeleton density of organic matter.

[0143] Optionally, the device further comprises:

[0144] A comparison module is used to compare the organic carbon content with a predetermined core test result; and to compare the porosity with a predetermined core test result.

[0145] A shale pore type identification device provided in an embodiment of the present invention can execute a shale pore type identification method provided in any embodiment of the present invention, and has corresponding functional modules and beneficial effects of the execution method.

[0146] Embodiment 3

[0147] Fig.11 A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or required herein.

[0148] like Fig.11As shown, the electronic device 10 includes at least one processor 11, and a memory connected to the at least one processor 11, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., wherein the memory stores a computer program that can be executed by at least one processor, and the processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 to the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0149] A number of components in the electronic device 10 are connected to the I / O interface 15, including: an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network such as the Internet and / or various telecommunication networks.

[0150] The processor 11 may be a variety of general and / or special processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as a shale pore type identification method.

[0151] In some embodiments, a shale pore type identification method may be implemented as a computer program, which is tangibly contained in a computer-readable storage medium, such as a storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the shale pore type identification method described above may be performed. Alternatively, in other embodiments, the processor 11 may be configured to perform a shale pore type identification method in any other appropriate manner (e.g., by means of firmware).

[0152] Various implementations of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), load programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various implementations can include: being implemented in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0153] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flow chart and / or block diagram are implemented. The computer program may be executed entirely on the machine, partially on the machine, partially on the machine and partially on a remote machine as a stand-alone software package, or entirely on a remote machine or server.

[0154] In the context of the present invention, a computer-readable storage medium may be a tangible medium that may contain or store a computer program for use by or in combination with an instruction execution system, device or equipment. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. A more specific example of a machine-readable storage medium may include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0155] To provide interaction with a user, the systems and techniques described herein may be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and a pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices may also be used to provide interaction with the user; for example, the feedback provided to the user may be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user may be received in any form (including acoustic input, voice input, or tactile input).

[0156] The systems and techniques described herein may be implemented in a computing system that includes backend components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes frontend components (e.g., a user computer with a graphical user interface or a web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such backend components, middleware components, or frontend components. The components of the system may be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0157] A computing system may include a client and a server. The client and the server are generally remote from each other and usually interact through a communication network. The client and server relationship is generated by computer programs running on the corresponding computers and having a client-server relationship with each other. The server may be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system to solve the defects of difficult management and weak business scalability in traditional physical hosts and VPS services.

[0158] It should be understood that the various forms of processes shown above can be used to reorder, add or delete steps. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and this document does not limit this.

[0159] The above specific implementations do not constitute a limitation on the protection scope of the present invention. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations and substitutions can be made according to design requirements and other factors. Any modification, equivalent substitution and improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method for identifying shale pore types, characterized in that: include: Based on the sonic wave, resistivity and gamma of the logging curve, the organic carbon content of the target layer in the study area is calculated; According to the acoustic wave of the well logging curve, the porosity of the target layer section in the study area is calculated; Determine the organic porosity using the organic carbon content and surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter; Based on the organic carbon content and porosity, an organic pore estimation chart is constructed, and based on the organic porosity estimation chart and organic porosity, semi-quantitative identification of the pore type of highly mature shale is performed.

2. The method according to claim 1, characterized in that According to the acoustic wave, resistivity and gamma of the logging curve, the organic carbon content of the target layer in the study area is calculated, including: The organic carbon content was calculated using the following formula; TOC=A*P AC +B*log10 (RT) +C*GR+D; Among them, TOC represents organic carbon content, P AC represents the acoustic wave of the logging curve, RT represents resistivity, GR represents gamma, and A, B, C, and D represent constants respectively.

3. The method according to claim 1, characterized in that According to the acoustic wave of the well logging curve, the porosity of the target layer section in the study area is calculated, including: The porosity was calculated using the following formula; BY=A*P AC +B; Where POR represents porosity, P AC represents the acoustic wave of the logging curve, and A and B represent constants respectively.

4. The method according to claim 1, characterized in that The organic porosity is determined by using the organic carbon content and the surface ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter, including: The surface ratio is calculated based on the predetermined organic pore volume and the apparent volume of organic matter, wherein the apparent volume of organic matter is used to characterize the overall volume of organic matter; The organic carbon content and the surface porosity, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of the organic matter are combined and calculated to determine the organic porosity.

5. The method according to claim 4, characterized in that Based on the predetermined organic pore volume and organic matter apparent volume, the surface ratio is calculated, including: The surface ratio is calculated by dividing the organic pore volume and the apparent volume of organic matter.

6. The method according to claim 4, characterized in that The organic carbon content and the surface ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon index, the apparent density of the shale, and the skeleton density of organic matter are combined and calculated to determine the organic porosity, including: The organic porosity was calculated using the following formula; Among them, POR Organic represents organic porosity, S represents surface porosity, TOC represents organic carbon content, Tr represents the percentage of organic carbon in shale converted into hydrocarbons, Cs represents carbon content index, ρ rock represents the apparent density of shale, ρ organic Represents the skeleton density of organic matter.

7. The method according to claim 1, characterized in that The method further comprises: The organic carbon content is compared to predetermined core test results; and the porosity is compared to predetermined core test results.

8. A shale pore type identification device, characterized in that: include: The organic carbon content calculation module is used to calculate the organic carbon content of the target layer in the study area based on the acoustic wave, resistivity and gamma of the logging curve; A porosity calculation module, used to calculate the porosity of the target layer section in the study area according to the acoustic wave of the logging curve; An organic porosity determination module is used to determine the organic porosity using the organic carbon content and the surface ratio, the percentage of organic carbon in the shale converted into hydrocarbons, the carbon content index, the apparent density of the shale, and the skeleton density of the organic matter; The high-maturity shale pore type identification module is used to construct an organic pore estimation map based on the organic carbon content and porosity, and to semi-quantitatively identify the high-maturity shale pore type based on the organic porosity estimation map and organic porosity.

9. An electronic device, characterized in that: The electronic device comprises: at least one processor; and a memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute a shale pore type identification method as described in any one of claims 1-7.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement a shale pore type identification method according to any one of claims 1 to 7 when executed.

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