Shale oil in-situ conversion section heating rock mass multi-dimensional multi-parameter characterization method and device

Abstract

The invention discloses a shale oil in-situ conversion section heating rock mass multi-dimensional multi-parameter characterization method and device, and the method comprises the steps: obtaining the binary lithologic data of a drilled organic matter-rich shale development section in a research area, and recognizing a quasi in-situ conversion section according to the upper limit of the proportion of non-organic matter-rich shale in the in-situ conversion section; according to the binarization lithology and TOC distribution characteristics, the quasi-in-situ conversion section is divided into at least one heating rock mass; identifying a non-rich organic matter shale single layer in the heated rock mass, and if the thickness is greater than the lower limit of the thickness of the single layer serving as a quasi-in-situ conversion section interlayer, identifying the interlayer; and establishing a well connection grid diagram of the drilled well, and completing the spatial distribution research of the heating rock mass of each well connection section and the interlayer body in the well connection section according to the single well recognition. According to the method, the binary lithologic data and the organic matter abundance can be combined to finely divide the heating rock mass; the interlayer in the heated rock mass is identified through a visual and easily-obtained interlayer thickness lower limit value, and finally, the spatial distribution research of the heated rock mass and the interlayer body in the heated rock mass is realized.

Description

Technical Field

[0001] The present invention relates to the technical field of geophysics and shale oil development, and in particular to a multi-dimensional and multi-parameter characterization method and device for heating rock mass in an in-situ conversion section of shale oil. Background Art

[0002] In the process of conventional oil and gas reservoir development, in order to improve the degree of oil and gas recovery and development benefits, a series of methods and technologies such as geological modeling and reservoir modeling have been established to finely characterize the characteristics of the target rock mass and its hosted fluids. Since the development objects and development methods are different from conventional oil and gas and other unconventional oil and gas resources, the existing geological body characterization technology cannot adapt well to the fine characterization of the various parameters of the in-situ heated shale rock mass, which is the development object in the field of shale oil in-situ conversion. The existing evaluation and characterization of shale oil in-situ conversion development objects are mostly at the scale of favorable areas and sweet spots in the plane (Yang Zhi, Zou Caineng, Fu Jinhua, et al. Evaluation of continental shale selection based on in-situ conversion / modification technology - taking the shale of the 7th section of the Triassic Yanchang Formation in the Ordos Basin as an example, 2017; Patent authorization announcement number: CN 109113730 B); vertically, 5 conditions for determining the heating section are given (Zhao Wenzhi, Hu Suyun, Hou Lianhua. The connotation and strategic position of underground in-situ conversion of shale oil, 2018). However, during the in-situ conversion and development phase of shale oil, the research results and evaluation methods for favorable areas and sweet spots are too large-scale to be applied to the detailed characterization of specific heated rock masses; there is a basis for determining the vertical heating section, but there is a lack of operational methods and processes.

[0003] The detailed characterization and representation of heated rock mass characteristics play a vital role in the selection of optimal heating section, reserve and production estimation, well pattern design, development mode optimization, oil production engineering design and other links in the process of shale oil in-situ conversion and development. Based on this, it is necessary to establish a detailed characterization method of heated rock mass characteristics suitable for the characteristics of this technology according to the connotation of shale oil in-situ conversion technology. Summary of the invention

[0004] In order to at least partially solve the technical problems existing in the prior art, the inventors have made the present invention, and through a specific implementation method, provide a multi-dimensional and multi-parameter characterization method and device for the heated rock mass in the in-situ conversion section of shale oil, which combines binary lithological data with organic matter abundance to finely divide the heated rock mass; identifies the interlayers in the heated rock mass through the intuitive and easily accessible lower limit of the interlayer thickness, and ultimately realizes the spatial distribution study of the heated rock mass and the interlayer bodies therein.

[0005] In a first aspect, an embodiment of the present invention provides a multi-dimensional and multi-parameter characterization method for a heated rock mass in an in-situ conversion stage of shale oil, comprising:

[0006] Obtaining binary lithology data of organic-rich shale development sections developed in target layers in wells drilled in the study area, wherein the binary lithology data includes organic-rich shale and non-organic-rich shale;

[0007] According to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, at least one pseudo-in-situ conversion section is identified from the organic-rich shale development section, and according to the distribution characteristics of the binary lithology and the TOC distribution characteristics, the pseudo-in-situ conversion section is divided into at least one heated rock mass;

[0008] Identify a non-organic-rich shale monolayer in the heated rock mass, and if the thickness of the non-organic-rich shale monolayer is greater than a lower limit of the monolayer thickness as an interlayer of the proposed in-situ conversion stage, identify the non-organic-rich shale monolayer as an interlayer, wherein the lower limit of the monolayer thickness is predetermined based on an average value of hydrocarbon generation potential values ​​of the organic-rich shale monolayer in the shale layer and a plurality of data pairs including the thickness of the non-organic-rich shale monolayer and its hydrocarbon generation potential value;

[0009] A well-connected grid diagram of the drilled wells is established, and based on the identification results of the heated rock mass and interlayer of a single well, a spatial distribution study of the heated rock mass and the interlayer therein of each well-connected section in the well-connected grid diagram is completed.

[0010] In a second aspect, an embodiment of the present invention provides a multi-dimensional and multi-parameter characterization device for heated rock mass in an in-situ conversion section of shale oil, the device comprising a binary lithology data acquisition module, a heated rock mass division module, an interlayer identification module, a heated rock mass distribution feature research module, and an interlayer single layer thickness lower limit determination module;

[0011] The binary lithology data acquisition module is used to acquire binary lithology data of the organic-rich shale development section developed in the target layer in the studied block, wherein the binary lithology data includes organic-rich shale and non-organic-rich shale;

[0012] The heated rock mass division module is used to identify at least one pseudo-in-situ conversion section from the organic-rich shale development section according to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, and divide the pseudo-in-situ conversion section into at least one heated rock mass according to the distribution characteristics of the binary lithology and the TOC distribution characteristics;

[0013] The interlayer identification module is used to identify a non-organic-rich shale single layer in the heated rock mass. If the thickness of the non-organic-rich shale single layer is greater than the lower limit of the single layer thickness of the interlayer in the proposed in-situ conversion section, the non-organic-rich shale single layer is identified as an interlayer. The lower limit of the single layer thickness is predetermined by the interlayer single layer thickness lower limit determination module based on the average hydrocarbon generation potential value of the organic-rich shale single layer in the shale layer and a plurality of data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value;

[0014] The heated rock mass distribution characteristic research module is used to establish a well-connected grid diagram of drilled wells, and complete the spatial distribution research of the heated rock mass and the interlayer body therein in each well-connected section in the well-connected grid diagram based on the heated rock mass and interlayer identification results of a single well.

[0015] In a third aspect, an embodiment of the present invention provides a computer storage medium, in which computer executable instructions are stored. When the computer executable instructions are executed by a processor, the multi-dimensional and multi-parameter characterization method of the heated rock mass in the in-situ conversion stage of shale oil is implemented.

[0016] In a fourth aspect, an embodiment of the present disclosure provides a server, comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, the multi-dimensional and multi-parameter characterization method for heated rock mass in the in-situ conversion stage of shale oil is implemented.

[0017] The beneficial effects of the above technical solution provided by the embodiment of the present invention include at least:

[0018] (1) The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the embodiment of the present invention, on a single well, based on the binary lithology data of the organic-rich shale development section, identifies the quasi-in-situ conversion section according to the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section; further subdivides the heated rock mass based on the binary lithology difference and TOC difference for the quasi-in-situ conversion section; identifies the interlayer in the heated rock mass through the intuitive and easy-to-obtain lower limit of the interlayer thickness; and completes the spatial distribution study of the heated rock mass and the interlayer body therein in each well-connected section in the well-connected grid diagram based on the knowledge of a single well. From single well to well-connected wells to well-connected grid diagrams, from the characterization of the heated rock mass to the tracking of the interlayer body therein, a multi-dimensional and multi-parameter characterization of the heated rock mass is achieved, providing an important reference for the design of subsequent development plans.

[0019] (2) The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the embodiment of the present invention, based on the binary lithology data of the organic-rich shale development section, identifies the quasi-in-situ conversion section according to the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section; further subdivides the heated rock mass in the quasi-in-situ conversion section based on the binary lithology difference and TOC difference, making it possible to adopt different well layout methods, heating schemes and subsequent oil and gas development schemes for the heated rock mass with different geological and geochemical conditions, and providing an important geological evaluation means for the scale-effective development of in-situ conversion of shale oil. That is, the on-site significance of this achievement is to make it possible to design the in-situ conversion development scheme in a refined and differentiated manner.

[0020] (3) The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the embodiment of the present invention predetermines the lower limit of the single-layer thickness of the non-organic-rich shale as the interlayer of the proposed in-situ conversion section based on the average value of the hydrocarbon generation potential of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value; if the thickness of the non-organic-rich shale single layer is determined to be greater than the lower limit of the single-layer thickness as the interlayer, it is determined to be an interlayer. First, this method is targeted at the specific application scenario of the organic-rich shale development section, breaking the limitation of the traditional identification of interlayers based solely on lithology, and is more suitable for geological evaluation and related research on the in-situ conversion of shale oil; in addition, this method converts the lower limit of the hydrocarbon generation potential of the interlayer into a more intuitive and easier to obtain lower limit of the interlayer thickness, reducing the requirements for data, and only lithology data is needed to realize the identification of the interlayer of the proposed in-situ conversion section of shale oil. The direct reason why the lower limit of the hydrocarbon generation potential of the interlayer can be converted into the lower limit of the thickness of the interlayer in this way is that the thickness of the interlayer has a relatively significant statistical relationship with the hydrocarbon generation potential of the interlayer; and the fundamental reason is that the enrichment of organic matter requires an extremely low deposition rate, and the smaller the thickness of the interlayer single layer and the faster the deposition rate, the more difficult it is to enrich the organic matter, and the worse the hydrocarbon generation potential is.

[0021] (4) The multi-dimensional and multi-parameter characterization method for the heated rock mass of the in-situ conversion section of shale oil provided in the embodiment of the present invention determines that the data on which the lower limit of the single-layer thickness of the non-organic-rich shale as the interlayer of the pseudo-in-situ conversion section depends are the average value of the hydrocarbon generation potential value of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value, which are obtained in the following way: according to the binary lithological data of the continuous coring section in the shale layer and the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section, the pseudo-in-situ conversion section is identified from the coring section; according to the sedimentary cycle, the pseudo-in-situ conversion section is identified from the coring section. The identified pseudo-in-situ conversion section is divided into multiple units, and the type of each unit is determined according to the thickness ratio of the pseudo-in-situ conversion section, and at least one unit is selected from each type of unit; millimeter-level lithology description is carried out on the selected units, and the units are divided into multiple organic-rich shale single layers and non-organic-rich shale single layers according to the description results. Rock samples are cut from the single layers, and the hydrocarbon generation potential of the rock samples is determined by pyrolysis test; the average value of the hydrocarbon generation potential of the organic-rich shale single layer and multiple data pairs containing the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential are statistically obtained. Taking into full consideration the geological characteristics of the continental shale formation, such as rapid lithology changes and thin single layer thickness, the basic workload is greatly reduced through lithology combination division, multi-level core fine description, and multi-scale sampling layer screening, while taking into account the lithology representativeness and high sampling accuracy of the collected samples.

[0022] (5) The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the embodiment of the present invention is aimed at the specific scenario of thin interlayer lithology identification in the organic-rich shale development section. It abandons the universal pursuit of conventional well logging lithology interpretation to interpret and characterize various lithologies developed in the study area separately, and limits the lithology interpretation objects to two types: organic-rich shale and non-organic-rich shale, thereby reducing the multi-solution of well logging lithology interpretation and improving the interpretation accuracy; at the same time, it reduces the amount of calculation and improves the recognition speed of batch interpretation of multiple wells.

[0023] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0024] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0025] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0026] Figure 1 This is a flow chart of a method for determining a lower limit of the thickness of a single layer of non-organic-rich shale as an interlayer in Example 1 of the present invention;

[0027] Figure 2 This is a flow chart of a method for establishing a lithology identification model for an organic-rich shale development segment based on lithology binarization in Embodiment 2 of the present invention;

[0028] Figure 3 This is a flow chart of a multi-dimensional and multi-parameter characterization method for heating rock mass in the in-situ conversion stage of shale oil in Example 3 of the present invention;

[0029] Figure 4 This is a flow chart of a method for synchronously screening multiple wells, multiple curves and multiple lithology sensitivity curves in Embodiment 4 of the present invention;

[0030] Figure 5 This is an example diagram of the synchronous comparison and screening of sensitivity curves of all sample points and the lithology distribution vein line in the fourth embodiment of the present invention;

[0031] Figure 6 This is a flow chart of a method for determining the plugging thickness of a complex lithology layer based on a simplified lithology combination in Embodiment 5 of the present invention;

[0032] Figure 7 It is a comprehensive histogram of the core wells at both ends of the long axis of the rock mass to be heated in the sixth embodiment of the present invention;

[0033] Figure 8 for Figure 7 Example of one-dimensional single well division of the heating stratigraphic unit of the core well 1;

[0034] Fig. 9 This is the situation of two-dimensional well connection characterization of the north-south heated rock mass in the shale oil in-situ conversion development area in Example 6 of the present invention;

[0035] Fig.10 This is the situation of characterizing the thickness of the heated rock mass in the shale oil in-situ conversion development block in Example 6 of the present invention;

[0036] Fig.11 This is the case of characterizing the thickness of the heated rock mass top plate in the shale oil in-situ conversion development block in Example 6 of the present invention;

[0037] Fig.12 This is the situation represented by the three-dimensional fence diagram of the heated rock mass in the shale oil in-situ conversion development zone in Example 6 of the present invention;

[0038] Fig.13 It is a schematic diagram of the structure of a multi-dimensional and multi-parameter characterization device for heating rock mass in the in-situ conversion stage of shale oil in an embodiment of the present invention. DETAILED DESCRIPTION

[0039] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0040] It should be understood that the terms described in the present invention are only for describing special embodiments and are not intended to limit the present invention. In addition, for the numerical range in the present invention, it should be understood that each intermediate value between the upper and lower limits of the scope is also specifically disclosed. Each smaller range between the intermediate value in any stated value or stated range and any other stated value or intermediate value in the described range is also included in the present invention. The upper and lower limits of these smaller ranges can be independently included or excluded in the scope.

[0041] Unless otherwise indicated, all technical and scientific terms used herein have the same meanings as commonly understood by those skilled in the art to which the invention belongs. Although the present invention describes only preferred methods and materials, any methods and materials similar or equivalent to those described herein may also be used in the implementation or testing of the present invention. All documents mentioned in this specification are incorporated by reference to disclose and describe the methods and / or materials related to the documents. In the event of a conflict with any incorporated document, the content of this specification shall prevail.

[0042] The embodiment of the present application divides organic-rich shale and non-organic-rich shale based on the TOC lower limit of organic-rich shale. Specifically, the lithology of rocks with TOC greater than the lower limit is defined as organic-rich shale; and the lithology of rocks with TOC not greater than the lower limit is defined as non-organic-rich shale.

[0043] The lower limit of TOC of organic-rich shale is flexibly set according to the actual geological conditions of the study area, and can usually be set to 2%, 3% or 5%. Optionally, it can also be set to other values.

[0044] Embodiment 1

[0045] Embodiment 1 of the present invention provides a method for determining the lower limit of the thickness of a single layer of non-organic-rich shale as an interlayer of a pseudo-in-situ conversion section of a shale layer, specifically determining the lower limit of the thickness of the non-organic-rich shale interlayer identified from the pseudo-in-situ conversion section in the shale layer, referring to Figure 1 As shown, the following steps are included:

[0046] Step S11: According to the binary lithology data of the core section of the target layer of the sample well and the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section, identify the quasi-in-situ conversion section from the core section, divide the identified quasi-in-situ conversion section into multiple units, determine the type of each unit according to the thickness ratio of the quasi-in-situ conversion section, and select at least one unit from each type of unit.

[0047] First, typical dissected wells used to identify interlayers with low hydrocarbon generation potential are selected. Generally, typical dissected wells must meet the following requirements:

[0048] (1) The dissecting well must be located in the shale oil in-situ conversion development block, or at least adjacent to the development block;

[0049] (2) at least one well;

[0050] (3) There is a continuous coring section in the shale section to be heated for in-situ conversion of shale oil.

[0051] Binary lithology data of the coring section, including organic-rich shale and non-organic-rich shale, can be obtained from core description data, thin section identification data and TOC detection data of the coring section of the target layer of the sample well, and the acquisition process includes the following as described in Example 2.

[0052] The binary lithology data of the coring section here needs to be centimeter-level lithology data.

[0053] The thickness of non-organic-rich shale in the simulated in-situ conversion section identified from the coring section is less than the set upper limit of the non-organic-rich shale ratio in the in-situ conversion section.

[0054] The upper limit of the proportion of non-organic-rich shale in the in-situ conversion stage can usually be set to 20%. Optionally, it can also be set to other values ​​according to relevant regulations or actual research needs.

[0055] In some embodiments, the quasi-in-situ conversion section can be divided into multiple units according to the sedimentation cycle, that is, divided into multiple sedimentation cycles, with a single sedimentation cycle as a unit.

[0056] Each unit is classified into one of the following types according to its thickness ratio to the proposed in-situ conversion section:

[0057] (1) The thickness ratio of the proposed in-situ conversion section is less than 1%,

[0058] (2) The thickness ratio of the proposed in-situ conversion section is not less than 1% and not more than 5%,

[0059] (3) The thickness ratio of the proposed in-situ conversion section is greater than 5% and less than 10%,

[0060] (4) The thickness ratio of the proposed in-situ conversion section is greater than 10%.

[0061] The basis for this classification is that the thickness of a single sedimentary cycle is affected by the comprehensive influence of the sedimentary paleoenvironment, which will affect the abundance of organic matter in the lithological combination section.

[0062] Screening the same number of units from each type of unit can be done by screening a typical unit from each type of unit, or by screening multiple units if the research time and conditions permit.

[0063] Step S12: Perform millimeter-level binary lithology description on the screened units, divide the units into multiple organic-rich shale monolayers and non-organic-rich shale monolayers according to the description results, cut rock samples from the monolayers, and determine the hydrocarbon generation potential of the rock samples through pyrolysis testing.

[0064] Based on the millimeter-level binary lithology description of the selected units, the following steps are performed:

[0065] (1) Using wire cutting technology, cut each lithologic single layer of each unit (sampling layer) along the lithologic single layer plane, and prepare independent flaky rock samples for each lithologic single layer. The thickness of the rock sample is the thickness of the single layer, and the volume of a single rock sample must meet the mass required for rock pyrolysis (preferably, not less than 5 grams); (2) Conduct rock pyrolysis test on each rock sample; (3) Calculate the sum of free hydrocarbons (S1) (unit: mg / g, the amount of free hydrocarbons in the rock per unit mass) and pyrolysis hydrocarbons (S2) (unit: mg / g, the amount of hydrocarbons generated after pyrolysis of the rock per unit mass) of each pyrolysis rock sample as the hydrocarbon generation potential value of the rock sample.

[0066] Step S13: Statistically obtain an average value of the hydrocarbon generation potential value of the organic-rich shale single layer and a plurality of data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value.

[0067] The data relied on for determining the lower limit of the single-layer thickness of the non-organic-rich shale as an interlayer of the pseudo-in-situ conversion section are the average value of the hydrocarbon generation potential of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential, which are obtained in the following way: according to the binary lithology data of the continuous coring section in the shale layer and the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section, the pseudo-in-situ conversion section is identified from the coring section; the identified pseudo-in-situ conversion section is divided into multiple units according to the sedimentary cycle, the type of each unit is determined according to the thickness ratio of the pseudo-in-situ conversion section, and at least one unit is selected from each type of unit; millimeter-level lithology description is carried out on the selected units, and the units are divided into multiple organic-rich shale single layers and non-organic-rich shale single layers according to the description results, rock samples are cut from the single layers, and the hydrocarbon generation potential of the rock samples is determined by pyrolysis test; the average value of the hydrocarbon generation potential of the organic-rich shale single layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential are statistically obtained. Fully considering the geological characteristics of continental shale formations such as rapid lithology changes and thin single layer thickness, through lithology combination division, multi-level core detailed description, and multi-scale sampling layer screening, the basic workload was greatly reduced while taking into account the lithology representativeness and high sampling accuracy of the collected samples.

[0068] Step S14: According to each data pair, a sample point is obtained, which includes the ratio of the thickness and hydrocarbon generation potential value of the non-organic-rich shale layer to the average value of the hydrocarbon generation potential value of the organic-rich shale layer.

[0069] Step S15: Project the sample points into a coordinate system, obtain a trend line by fitting, and determine the ratio of the hydrocarbon generation potential value to the average hydrocarbon generation potential value of the organic-rich shale single layer according to the trend line as the thickness of the non-organic-rich shale single layer corresponding to the set ratio, and determine the thickness as the lower limit of the single layer thickness of the non-organic-rich shale single layer as the interlayer of the quasi-in-situ conversion section.

[0070] The coordinate system uses the thickness of a single layer of non-organic-rich shale and the ratio of the hydrocarbon generation potential value of a single layer of non-organic-rich shale to the average hydrocarbon generation potential value of a single layer of shale (hydrocarbon generation potential value of a single layer of non-organic-rich shale / average hydrocarbon generation potential value of a single layer of shale) as coordinate axes.

[0071] The above-mentioned set ratio is usually 38% to 42%; preferably, it is 40%.

[0072] Taking the setting ratio of 40% as an example, 40% of the average hydrocarbon generation potential value of all organic-rich shale monolayers in the quasi-in-situ conversion section is used as the lower limit of the hydrocarbon generation potential of the interlayer of the quasi-in-situ conversion section; then, through the above-mentioned thickness conversion, the lower limit of the monolayer thickness of the non-organic-rich shale monolayer as the interlayer of the quasi-in-situ conversion section is obtained.

[0073] The direct reason why Example 1 of the present application can convert the lower limit value of the hydrocarbon generation potential of the interlayer into the lower limit value of the thickness of the interlayer is that the thickness of the interlayer has a relatively significant statistical relationship with the hydrocarbon generation potential of the interlayer; and the fundamental reason is that the enrichment of organic matter requires an extremely low deposition rate, and the smaller the thickness of the interlayer single layer, the faster the deposition rate, the more difficult it is to enrich the organic matter, and the worse the hydrocarbon generation potential is.

[0074] Embodiment 2

[0075] The second embodiment of the present invention provides a method for establishing a lithology identification model for an organic-rich shale development segment based on lithology binarization. Figure 2 As shown, the following steps are included:

[0076] Step S21: Determine the lower limit of the GR value of the organic-rich shale based on the binary lithology data of the core section of the target layer of the sample well.

[0077] Wells cored in the target layer of the study area are selected as sample wells; optionally, the selected wells can be divided into sample wells and verification wells. The relevant data of the verification wells do not participate in the training of the model and are only used for the later verification of the model.

[0078] Specifically, the binary lithology data of the coring section, including organic-rich shale and non-organic-rich shale (i.e., interlayer), is obtained by the following steps:

[0079] (1) Based on the thin section identification data of the core sampling section of the target layer of the sample well, the lithology description data in the core description data is corrected to obtain preliminary lithology data, which includes mud shale.

[0080] The lithology description data in the core description data is only the lithology description made by geologists based on their experience of visual observation of the core. Due to the limitations of visual observation and the influence of subjective factors, the accuracy of the lithology description data needs to be further corrected. The thin section identification data can accurately realize the lithology naming, but the thin section identification data has limited sampling after all. Therefore, the lithology description data in the core description data is based on the verification of the thin section identification data to obtain preliminary lithology data.

[0081] The preliminary description data obtained may include clastic rocks such as shale, coarse sandstone, medium sandstone, fine sandstone and siltstone, and may also include carbonate rocks or other rock types.

[0082] (2) Based on the TOC detection data, the mudstone with a TOC value greater than the preset lower limit of the TOC of organic-rich shale in the preliminary lithological data is determined as organic-rich shale, and the binary lithological data of the coring section is obtained.

[0083] Thin section identification data can be used to accurately identify lithology at the millimeter level, but thin section identification data cannot distinguish whether mud shale is organic-rich shale or non-organic-rich shale. At this time, it is also necessary to refer to the TOC value, and mud shale with a TOC value not greater than the lower limit of the TOC of organic-rich shale, as well as other lithologies other than mud shale, are identified as non-organic-rich shale.

[0084] It can be seen that the organic-rich shale in this embodiment is defined based on the lower limit of TOC of organic-rich shale, and the shale that meets the lower limit is organic-rich shale; the organic-rich shale development section refers to a rock formation composed of organic-rich shale and its interlayers.

[0085] The lower limit of TOC of organic-rich shale is flexibly set according to the actual geological conditions of the study area, and can usually be set to 2%, 3% or 5%. Optionally, it can also be set to other values.

[0086] Mud shale with a TOC value not greater than the lower limit of the TOC value of organic-rich shale, as well as other lithologies except mud shale, are identified as non-organic-rich shale.

[0087] Determining the lower limit of the GR value of organic-rich shale may include, based on the lithology data and the GR curve of the sample well, extracting the lithology and GR value of the sampling points with thin section identification data and TOC detection data; and obtaining the lower limit of the GR value of the organic-rich shale based on the lithology and GR values ​​of multiple sampling points.

[0088] Since the interlayer identification in this embodiment is based on the well logging curve, the well logging curve of the sample well must first be standardized; after obtaining the preliminary lithology data or binary lithology data of the coring section, the standardized well logging curve is depth-reset.

[0089] The GR values ​​of the above sampling points are extracted from the GR curve after standardization and depth relocation.

[0090] Step S22: taking the binary lithology data of the coring section and the curve section of the selected sensitive curve as a sample to establish a sample set.

[0091] In some embodiments, after obtaining the binary lithology data of the coring section, the method further includes screening the sensitivity curves of organic-rich shale and non-organic-rich shale from all types of well logging curves of the sample well. The specific screening method may adopt the method in the following embodiment 4, or other conventional methods.

[0092] Step S23: Use the sample set to train the selected neural network model, establish a lithology recognition model, and input the GR value lower limit into the lithology recognition model.

[0093] Embodiment 3

[0094] Embodiment 3 of the present invention provides a multi-dimensional and multi-parameter characterization of the heated rock mass in the in-situ conversion stage of shale oil, see Figure 3 As shown, the following steps are included:

[0095] Step S31: Obtain binary lithology data of organic-rich shale development sections developed in target layers in wells drilled in the study area.

[0096] Binary lithology data include organic-rich shales and non-organic-rich shales.

[0097] If the well has been drilled and coring is carried out in the target layer, and the coring section passes through the organic-rich shale development section of the target layer, the binary lithology data of the organic-rich shale development section can be obtained based on the core description data, thin section identification data and TOC detection data. The specific method is described in Example 2.

[0098] If the well has been drilled and coring is done in the target layer, but the coring section does not pass through the organic-rich shale development section of the target layer, and only part of the coring is done, the binary lithology data of the coring section shall be used as the standard, and the binary lithology data of the entire organic-rich shale development section shall be obtained in combination with the logging interpretation results for the section without coring.

[0099] For wells that have been drilled without coring, the binary lithology data of the organic-rich shale development section can be obtained by the following method:

[0100] The sensitivity curve of the drilled well is input into the lithology identification model, and the binary lithology data of the organic-rich shale development section is obtained according to the output result of the model. The lithology identification model is pre-established by the method in the above-mentioned embodiment 2.

[0101] The working principle of the lithology identification model is to preliminarily locate the organic-rich shale development section based on the GR value lower limit of the organic-rich shale and the GR curve of the drilled well. According to the neural network learning results of the corresponding sensitive curve section of the organic-rich shale development section, its binary lithology data is determined to obtain the results for output.

[0102] That is, the lower limit of the GR value of organic-rich shale is first used to roughly locate the organic-rich shale development section, and then the lithology identification model is used to make a fine and high-resolution binary lithology prediction for the organic-rich shale development section.

[0103] In some embodiments, before inputting the sensitivity curve of the drilled well into the lithology identification model, the process further includes removing the high GR value abnormal values ​​of non-organic-rich shale from the sensitivity curve of the drilled well using the rock logging data. For example, the interference of special high GR rocks on the high GR response of organic-rich shale is removed, such as high uranium content sandstone.

[0104] Step S32: According to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, at least one pseudo-in-situ conversion section is identified from the organic-rich shale development section.

[0105] That is, the identified simulated in-situ conversion section satisfies the requirement that the thickness of the non-organic-rich shale layer therein is less than the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section.

[0106] The upper limit of the proportion of non-organic-rich shale in the in-situ conversion stage can usually be set to 20%. Optionally, it can also be set to other values ​​according to relevant regulations or actual research needs.

[0107] Step S33: Divide the quasi-in-situ conversion section into at least one heated rock mass according to the distribution characteristics of the binary lithology and the TOC distribution characteristics.

[0108] It can be that a bar graph of a binary lithology profile and a TOC profile of the organic-rich shale development section is established.

[0109] Furthermore, if there is coring data for the organic-rich shale development section of the target well, the lithology profile is established based on the binary lithology description data of the coring data; if the binary lithology description data in the coring data is incomplete, the lithology data is supplemented in combination with the model output results to establish a binary lithology profile.

[0110] The establishment of the TOC profile can be, if there are continuous measured TOC values ​​(sampling interval is not more than 0.5 meters) in the organic-rich shale development section of the target well, the TOC profile is established using the measured TOC values; if there are no or only partial measured TOC values ​​in the organic-rich shale development section of the target well, the measured TOC values ​​are used first, and the interpreted TOC values ​​of the TOC interpretation model are used to supplement the measured TOC data for the remaining parts to establish the TOC profile.

[0111] Specifically, the division of the heated rock mass in the proposed in-situ conversion stage is based on the following principles:

[0112] The TOC difference between the heated rock mass and the adjacent heated rock mass satisfies a first set difference, and / or the lithology combination difference between the heated rock mass and the adjacent heated rock mass satisfies a second set difference.

[0113] Furthermore, the first set difference includes the difference in overall TOC value and / or the difference in overall TOC curve morphology; the second set difference includes the difference in the number of non-organic-rich shale layers and / or the difference in the thickness of non-organic-rich shale layers.

[0114] There are three situations in which a shale oil in-situ conversion heated rock mass is different from an adjacent heated rock mass. Situation 1: the heated rock mass and its adjacent heated rock mass have significantly different TOC value curve characteristics, such as: overall TOC value difference, or overall TOC value curve morphology difference. The specific difference needs to be determined in combination with actual conditions in different embodiments. Situation 2: there is no obvious TOC value curve characteristic difference between the heated rock mass and its adjacent heated rock mass, but there is an obvious lithologic combination difference, such as: the number of interlayers, or the difference in the thickness of a single interlayer, etc. The specific difference needs to be determined in combination with actual conditions in different embodiments. Situation 3: the heated rock mass and its adjacent heated rock mass have both TOC value curve characteristic differences and lithologic combination differences.

[0115] Step S34: Identify a non-organic-rich shale monolayer in the heated rock mass. If the thickness of the non-organic-rich shale monolayer is greater than the lower limit of the monolayer thickness as an interlayer in the simulated in-situ conversion section, identify the non-organic-rich shale monolayer as an interlayer.

[0116] The lower limit of the single layer thickness is predetermined based on the average value of the hydrocarbon generation potential value of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value. The specific determination method is described in Example 1.

[0117] After all the wells drilled in the study area (wells that have penetrated the target layer) have completed the above steps S31 to S34, step S35 is executed.

[0118] Step S35: Establish a well-connected grid diagram of the drilled wells, and complete the spatial distribution study of the heated rock mass and the interlayer body therein in each well-connected section in the well-connected grid diagram according to the identification results of the heated rock mass and interlayer of the single well.

[0119] The well-connected grid diagram covers all the wells drilled that penetrate the target layer.

[0120] The multi-dimensional and multi-parameter characterization method of the heated rock mass in the in-situ conversion section of shale oil provided in Example 3 of the present application, wherein the working principle of the binary lithology interpretation method is: based on the fact that organic-rich shale is formed in a reducing environment that makes uranium elements easier to precipitate, resulting in the characteristics of high uranium and high natural gamma that are different from other lithologies, natural gamma is combined with conventional rock cuttings logging to eliminate the interference of other non-shale high GR rocks (such as sandstone-type uranium mines), and the vertical distribution of high GR organic-rich shale development sections is identified. In the identified organic-rich shale development section, by automatically calculating the correlation between various conventional logging curves and organic-rich shale, the curve with the best correlation is directly selected as the input curve, and a neural network method is used to automatically establish a lithology identification model of organic-rich shale and non-organic-rich shale. The interpretation results are consistent with the actual results through continuous verification and iteration of the lithology identification model by the verification well. Finally, the front-end inputs various conventional logging curves, and the terminal automatically generates a high-precision lithology profile containing organic-rich shale and non-organic-rich shale.

[0121] The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the third embodiment of the present invention, in a single well, based on the binary lithology data of the organic-rich shale development section, identifies the quasi-in-situ conversion section according to the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section; further subdivides the heated rock mass based on the binary lithology difference and TOC difference for the quasi-in-situ conversion section; identifies the interlayer in the heated rock mass through the intuitive and easy-to-obtain lower limit of the interlayer thickness; and completes the spatial distribution study of the heated rock mass and the interlayer body therein in each well-connected section in the well-connected grid diagram based on the knowledge of a single well. From single well to well-connected well to well-connected grid diagram, from the characterization of the heated rock mass to the tracking of the interlayer body therein, the multi-dimensional and multi-parameter characterization of the heated rock mass is achieved, which provides an important reference for the design of subsequent development plans.

[0122] The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in the third embodiment of the present invention, based on the binary lithology data of the organic-rich shale development section, identifies the quasi-in-situ conversion section according to the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section; further subdivides the heated rock mass based on the binary lithology difference and TOC difference for the quasi-in-situ conversion section, making it possible to adopt different well layout methods, heating schemes and subsequent oil and gas development schemes for the heated rock mass with different geological and geochemical conditions, and providing an important geological evaluation means for the scale-effective development of in-situ conversion of shale oil. That is, the on-site significance of this achievement is to make it possible to design the in-situ conversion development scheme in a refined and differentiated manner.

[0123] The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in Example 3 of the present invention predetermines the lower limit of the single-layer thickness of the non-organic-rich shale as the interlayer of the proposed in-situ conversion section based on the average value of the hydrocarbon generation potential of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value; if it is determined that the thickness of the non-organic-rich shale single layer is greater than the lower limit of the single-layer thickness as the interlayer, it is determined to be an interlayer. First of all, this method is targeted at specific application scenarios of organic-rich shale development sections, breaking the limitations of traditional interlayer identification that relies solely on lithology, and is more suitable for geological evaluation and related research on shale oil in-situ conversion; in addition, this method converts the lower limit of the hydrocarbon generation potential of the interlayer into a more intuitive and easier to obtain lower limit of the interlayer thickness, reducing the requirements for data, and only lithology data is needed to identify the interlayer of the proposed in-situ conversion section of shale oil. The direct reason why the lower limit of the hydrocarbon generation potential of the interlayer can be converted into the lower limit of the thickness of the interlayer in this way is that the thickness of the interlayer has a relatively significant statistical relationship with the hydrocarbon generation potential of the interlayer; and the fundamental reason is that the enrichment of organic matter requires an extremely low deposition rate, and the smaller the thickness of the interlayer single layer and the faster the deposition rate, the more difficult it is to enrich the organic matter, and the worse the hydrocarbon generation potential is.

[0124] The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion section of shale oil provided in Example 3 of the present invention is aimed at the specific scenario of lithology identification of thin interlayers in the organic-rich shale development section. It abandons the universal pursuit of conventional well logging lithology interpretation to interpret and characterize various lithologies developed in the study area separately, and limits the lithology interpretation objects to two types: organic-rich shale and interlayers (non-organic-rich shale), thereby reducing the multi-solution of well logging lithology interpretation and improving the interpretation accuracy; at the same time, it reduces the amount of calculation and improves the recognition speed of batch interpretation of multiple wells.

[0125] The multi-dimensional and multi-parameter characterization method for the heated rock mass in the in-situ conversion stage of shale oil provided in the third embodiment of the present invention only needs to use the core data of the sample well in the stage of establishing the lithology identification model. Once the modeling is completed, only conventional logging curves need to be used in the application stage to achieve high-precision characterization of the binary lithology of organic-rich shale. Under the premise of ensuring the accuracy of interpretation, the requirements for data quality are greatly reduced.

[0126] In some embodiments, it may also include, for each heated rock mass, counting the heated rock mass thickness, interlayer thickness and interlayer thickness ratio of a single well, and drawing a heated rock mass thickness plane map, an interlayer thickness plane map and an interlayer thickness ratio plane map by interpolation method.

[0127] Embodiment 4

[0128] Embodiment 4 of the present invention provides a method for synchronously screening multiple wells, multiple curves and multiple lithology sensitivity curves, and the process thereof is as follows Figure 4 As shown, the following steps are included:

[0129] Step S41: Acquire multiple sample points of the target layer.

[0130] Each sample point includes the binary lithology type and the value of each curve to be screened.

[0131] The curve to be screened may be depth-calibrated based on the binary lithology data of the sample well in the second embodiment, and a matching relationship between the lithology data and the curve to be screened in depth may be established to obtain a well logging lithology calibration chart.

[0132] The extraction of sample points can be based on the sampling points of the logging curve. For example, if the logging curve is sampled at 0.125m, the sample points are also sampled at 0.125m, or the samples are sampled after thinning.

[0133] The sampling method of the above-mentioned sample points is different from the traditional method of using rock sample collection points as calibration points. This improvement will greatly improve the richness and vertical continuity of sample data.

[0134] Multiple wells with continuous core samples in the target layer of the study area can be identified as sample wells. The sample wells are representative and comprehensive, thereby greatly reducing the impact of geological heterogeneity on the accuracy of lithology sensitivity curve screening.

[0135] Step S42: Project each sample point into a coordinate system including multiple parallel axes, each axis corresponding to a different curve to be screened.

[0136] Based on the well logging lithology calibration chart, the numerical distribution range of each curve to be screened is statistically analyzed.

[0137] A coordinate system containing multiple parallel number axes is established, and the two ends of the number axes in the coordinate system are aligned, and the values ​​at both ends match the corresponding numerical distribution range. The values ​​at both ends can be consistent with the two end values ​​of the corresponding numerical distribution range, or the minimum value of the values ​​at both ends can be less than the minimum value in the numerical distribution range, and the maximum value of the values ​​at both ends can be greater than the maximum value in the numerical distribution range.

[0138] Taking the logging curve GR as an example, if the numerical distribution range of GR in the target layer is 200 API to 500 API, the two end values ​​of the number axis corresponding to the logging curve GR can be set to 200 API and 500 API respectively.

[0139] In some embodiments, the numerical values ​​of the axes in the established coordinate system change in the same direction.

[0140] Taking the example that all number axes are distributed vertically, the values ​​of each number axis gradually increase from top to bottom, or gradually decrease from top to bottom.

[0141] Step S43: Connect the projection points of the same sample point on different axes to obtain a vein line.

[0142] Use line type or color to distinguish rock types.

[0143] Step S44: Screen at least one type of lithology sensitivity curve according to the distribution characteristics of the vein lines.

[0144] In some embodiments, the method may include, according to the distribution characteristics of vein lines on the numerical axis, selecting at least one type of lithology sensitivity curve based on the following understandings:

[0145] The more the vein lines of organic-rich shale converge on a certain axis, and the more distinct the vein lines are from those of non-organic-rich shale, the more sensitive the corresponding screening curve to organic-rich shale is, and vice versa. Figure 5 shown.

[0146] The method for synchronously screening multi-well, multi-curve and multi-lithology sensitivity curves provided in the fourth embodiment of the present invention reduces the influence of human subjective factors in the sensitivity curve selection process and improves the objectivity of the selection results by converting the correlation between logging curves and lithology into a more intuitive line convergence degree and differentiation degree.

[0147] The method for synchronous screening of multi-well, multi-curve and multi-lithology sensitive curves provided in the fourth embodiment of the present invention establishes a coordinate system including multiple parallel axes, each axis corresponds to a different curve to be screened, and vein lines corresponding to different sample points are drawn in the coordinate system, so that curves of different types can be placed in the same coordinate system for synchronous comparison, thereby improving the accuracy of sensitive curve selection, making it less likely that sensitive curves will be missed, and greatly improving the screening efficiency.

[0148] The method for synchronous screening of multiple wells, multiple curves and multiple lithology sensitivity curves provided in the fourth embodiment of the present invention connects the projection points of the same sample point on different axes to obtain a vein line. One sample point corresponds to one vein line, and the possibility of two vein lines completely overlapping is very small, which avoids the situation of a large number of points overlapping caused by a simple point casting method, so that the final lithology distribution vein line map is more complete and representative.

[0149] In some embodiments, the multi-dimensional and multi-parameter characterization of the heated rock mass in the in-situ conversion section of shale oil can also characterize the lower limit of the sealing thickness of the overlying and underlying rock strata required for in-situ mining. The following Example 5 is illustrated by taking the determination of the lower limit of the sealing thickness of the overlying rock strata (complex lithology layers of siltstone and mudstone) as an example, and a similar method can be used to determine the lower limit of the sealing thickness of the underlying rock strata.

[0150] Embodiment 5

[0151] Embodiment 5 of the present invention provides a method for determining the sealing thickness of a complex lithology layer based on a simplified lithology combination, referring to Figure 6 As shown, the following steps are included:

[0152] Step S61: Determine the vertical superposition relationship between the siltstone layer and the mudstone layer, and the total thickness of the siltstone layer and the total thickness of the mudstone layer according to the lithology vertical distribution characteristics of the overlying strata within a set range.

[0153] The complex lithology layer is the overlying stratum of the shale reservoir, which is interbedded with siltstone and mud shale.

[0154] According to empirical data, the plugging thickness of the roof during in-situ mining of shale reservoirs is usually within 300-400 cm, so the length (thickness) of the roof rock sample is set to be no less than 500 cm. If it is thicker, the experimental difficulty and cost will increase; if it is thinner, it will easily fall below the lower limit of the actual plugging thickness of the roof, resulting in experimental failure (unable to measure the required roof plugging thickness of shale in-situ). That is, the setting range of the overlying stratum is within the range of 500 cm in thickness, preferably, within the range of 500 cm in thickness from the position closest to the top surface of the shale reservoir upward.

[0155] The set range is divided into an upper and a lower part by an averaging method. If the cumulative thickness of the lower shale layer exceeds the first set ratio (for example, exceeding 60%), the superposition relationship is determined to be the shale layer at the bottom and the siltstone layer at the top; if the cumulative thickness of the lower shale layer is lower than the second set ratio (for example, lower than 40%), the superposition relationship is determined to be the shale layer at the top and the siltstone layer at the bottom; if the cumulative thickness of the lower shale layer is within the set ratio range (for example, 40% to 60%), the lower part within the set range is further divided into an upper and a lower part by an averaging method, and the above method is repeated to determine the upper and lower superposition relationship of the siltstone layer and the shale layer.

[0156] Step S62: Based on the measured properties of the plurality of siltstone samples and the plurality of shale samples, and according to the upper and lower overlapping relationship and the total thickness of the siltstone layer and the total thickness of the shale layer, a roof rock sample is prepared by an integrated molding method.

[0157] Step S621: Based on the measured properties of multiple siltstone samples, a first formula of siltstone is prepared by experimental fitting, and based on the measured properties of multiple shale samples, a second formula of shale is prepared by experimental fitting.

[0158] In some embodiments, fitting of a first formula for preparing siltstone may include: measuring the particle size distribution, mineral composition, porosity, fracture pressure, critical fracture damage strain value, and minimum starting pressure of rock samples of each siltstone layer within a set range of the overlying stratum, and obtaining the average values ​​of the corresponding parameters by thickness-weighted averaging; preparing a siltstone sample using the average values ​​of the particle size distribution and the average values ​​of the mineral composition of the siltstone layer as the current formula, and adjusting the current formula until the errors between the porosity, fracture pressure, critical fracture damage strain value, and minimum starting pressure of the currently prepared siltstone sample and the corresponding average values ​​meet an error threshold, thereby obtaining the first formula for preparing siltstone.

[0159] Small-size samples can be synthesized first, the porosity of the synthesized samples can be measured, and then calibrated with the measurement results of natural samples. Then, the current particle size distribution and mineral composition can be adjusted and optimized, and new artificial samples can be synthesized. Finally, the error between the measurement results of the synthetic samples and the natural samples does not exceed the error threshold (which can be set to 15%).

[0160] In some embodiments, fitting of a second formula for preparing mud shale may include: measuring the particle size distribution, mineral composition, TOC, kerogen initial hydrocarbon production temperature, porosity, critical damage strain value of fracture and fracture pressure of rock samples of each mud shale layer within a set range of the overlying formation, and obtaining the average values ​​of the corresponding parameters by thickness weighting; taking the average values ​​of the particle size distribution and the average values ​​of the mineral composition of the mud shale layer as the current formula, preparing a mud shale sample, and adjusting the current formula until the errors between the TOC, kerogen initial hydrocarbon production temperature, porosity, critical damage strain value of fracture and fracture pressure of the mud shale sample currently prepared and the corresponding average values ​​all meet the error threshold, thereby obtaining the second formula for preparing mud shale.

[0161] Optionally, in the process of fitting the first formula and the second formula, the parameters used for calibration may include not only the above parameters but also other parameters. Correspondingly, the measurement results of natural samples of these parameters are obtained by measuring the measurement results of corresponding rock samples and averaging them by thickness weighted average.

[0162] Step S622: preparing a roof rock sample by an integrated molding method according to the upper and lower overlapping relationship, the total thickness of the siltstone layer and the total thickness of the shale layer, the first formula and the second formula.

[0163] Roof rock samples of the same cross-sectional area (eg, cylindrical with a diameter of 5 cm) may be prepared.

[0164] Taking the above setting range of 500 cm thickness as an example, the thickness of the roof rock sample is also 500 cm.

[0165] The sides of the roof rock sample are wrapped with heat-insulating materials. The heat insulation can prevent the heat from being dissipated to the surroundings during the heating process. The pressure resistance of the heat-insulating sealing material must be no less than 80MPa.

[0166] Step S63: a first heating device, a first pressurizing device, a first stress device and a group of first sensors are arranged on the bottom surface of the roof rock sample, and multiple groups of first sensors are arranged on the side of the roof rock sample at a first set interval, wherein the first sensor includes a first temperature sensor, a first pressure sensor and a first strain sensor; the roof rock sample is heated by the first heating device to a first set temperature measured by the first temperature sensor at the bottom, the roof rock sample is pressurized by the first pressurizing device to a first set pressure measured by the first pressure sensor at the bottom, the first stress device is used to gradually apply stress to the bottom of the roof rock sample from small to large to a first set stress, and stabilize at the temperature, the pressure and the stress until the measured value variation amplitude of each first sensor is less than the set threshold value, and the lower limit of the roof plugging thickness is determined according to the measured value of the first sensor and the upper and lower overlapping relationship.

[0167] In the embodiment of the present application, from bottom to top corresponds to from bottom to top.

[0168] The measuring positions of each group of first temperature sensors, first pressure sensors and first strain sensors arranged on the side of the rock sample in the longitudinal direction are consistent.

[0169] The first pressurizing device may be a fluid pressurizing device; and the first stress device may be a triaxial stress testing device.

[0170] In some embodiments, the first heating device is a unidirectional heating device to save resources.

[0171] The first heating device is located at the center of the bottom surface of the top plate rock sample. Further, the first heating device can directly heat the bottom surface of the top plate rock sample to no more than 1 / 4 of the bottom surface area, so that the heat source can be spread upward as much as possible.

[0172] The first temperature sensor and the first strain sensor are arranged axially on the side of the roof rock sample, and the first set interval of the arrangement is set according to the measurement accuracy requirement, usually at an interval of 10 cm.

[0173] In some embodiments, the first set temperature is the lowest temperature at which the kerogen conversion rate in the shale reservoir reaches a set conversion rate threshold.

[0174] The first set temperature can be determined by utilizing a source rock thermal simulation experiment or a kerogen activation energy experiment.

[0175] For example, multiple samples of shale reservoirs are taken, and source rock thermal simulation experiments are carried out respectively to measure the lowest temperature at which the kerogen conversion rate reaches a set conversion rate threshold, and the minimum value of the multiple minimum temperatures measured is determined as the first set temperature.

[0176] Furthermore, the first set temperature is the lowest temperature at which the kerogen conversion rate in the shale reservoir reaches 90%, usually 290-330°C.

[0177] The kerogen conversion rate reaches 90%. At this temperature, the reservoir almost completes the conversion to hydrocarbons and achieves maximum oil and gas production. That is, this temperature is the highest temperature at which the reservoir may be heated during the in-situ heating and exploitation of the actual shale reservoir. Therefore, the setting of this temperature ensures the safety and rationality of the lower limit of the roof plugging thickness.

[0178] In some embodiments, the first set pressure is the fracture pressure of the shale reservoir, which can be determined through a rock fracture pressure experiment; the first set stress is the maximum principal stress underground at the depth of the bottom surface of the roof rock sample, which is obtained by calculation.

[0179] The first set temperature, i.e., the lowest temperature T0 at which the kerogen conversion rate in the shale reservoir reaches 90%, is determined in the above manner, the fracture pressure P0 of the shale reservoir is determined, and the maximum underground principal stress Ex at the bottom burial depth of the roof rock sample is determined.

[0180] The first heating device (heat source) is used to heat slowly (no more than 20°C / day), with the maximum temperature of the heat source between 400 and 650°C. The power of the heat source is adjusted to keep the temperature at the bottom of the top plate rock sample constant at T0. The first pressurizing device is used to pressurize the bottom of the top plate rock sample, and fluid is used for pressurization. The pressurization speed does not exceed 300KPa / day (the specific value is flexibly set according to the on-site construction conditions), so that the pressure at the bottom of the top plate rock sample is constant at P0. At the same time, the first stress device is used to apply stress to the bottom of the top plate rock sample step by step, and each increase of 1MPa can be constant for 5 minutes, and the final applied stress is constant at Ex. Furthermore, try to make the stress reach Ex, the pressure reach P0, and the temperature reach T0 simultaneously. The temperature is constant T0, the pressure is constant P0, and the stress is constant Ex. They are stable for at least 30 minutes until the change amplitude of the measured values ​​of each sensor is less than the set threshold, that is, after the temperature, pressure and strain are stable, the measured values ​​of the first temperature sensor, the first pressure sensor and the first strain sensor are collected. Since the temperature of the roof rock sample gradually decreases from bottom to top, the pressure gradually decreases from bottom to top, and the strain also gradually decreases from bottom to top, the measured values ​​of the first temperature sensor, the first pressure sensor and the first strain sensor can be collected from bottom to top in sequence.

[0181] Before determining the lower limit of the top plate plugging thickness, the following parameters need to be determined:

[0182] The initial hydrocarbon production temperature Tx of the kerogen in the shale layer of the roof rock sample is usually 200-250°C. It can be determined by thermal simulation experiments of source rocks;

[0183] The fracture pressure Px of the roof rock sample can be the average value of the fracture pressures of the siltstone layer and the shale layer after weighted average of their thicknesses;

[0184] The critical damage strain value εx of the roof rock sample can be the average value of the critical damage strain value of the siltstone layer and the shale layer after the thickness weighted average;

[0185] The minimum starting pressure Ps for oil and gas migration in the siltstone layer in the roof rock sample.

[0186] In some embodiments, according to the measurement value of the first sensor and the vertical superposition relationship between the siltstone layer and the mudstone layer in the roof rock sample, the lower limit of the plugging thickness of the roof rock sample is determined to include the following two situations:

[0187] 1. The relationship between the upper and lower superposition is that the siltstone layer is on the upper

[0188] (1) If the temperature in the shale layer drops to Tx, the pressure drops to Px, and the strain drops to εx, determine the highest position among the position where the temperature is Tx, the position where the pressure is Px, and the position where the strain is εx, and determine the distance from this position to the bottom surface of the roof rock sample as the lower limit of the roof plugging thickness;

[0189] (2) If the temperature in the mudstone layer drops to Tx, but the pressure does not drop to Px and the strain does not drop to εx at the same time, and the minimum starting pressure of the siltstone layer is greater than the fracture pressure Pr of the shale reservoir, the distance from the higher position of the position where the pressure is Px and the position where the strain is εx to the bottom surface of the roof rock sample is determined as the lower limit of the roof plugging thickness; if the minimum starting pressure of the siltstone layer is not greater than the fracture pressure Pr of the shale reservoir, it is determined that the roof rock sample cannot be plugged;

[0190] (3) If the temperature in the shale layer is greater than Tx, the method is invalid.

[0191] 2. The relationship between the upper and lower superposition is that the siltstone layer is at the bottom.

[0192] (1) If the temperature in the siltstone layer drops to Tx, the pressure drops to Px, and the strain drops to εx, the thickness of the siltstone layer is determined to be the lower limit of the roof plugging thickness;

[0193] (2) If the strain in the shale layer drops to εx, or the pressure drops to Px, or the temperature drops to Tx, determine the highest position among the position where the temperature is Tx, the position where the pressure is Px, and the position where the strain is εx, and determine the distance from this position to the bottom surface of the roof rock sample as the lower limit of the roof plugging thickness.

[0194] In some embodiments, other factors affecting the plugging performance may be further considered to determine a safety correction factor (greater than 1), and the safety correction factor may be used to correct the lower limit of the roof plugging thickness determined above.

[0195] The method for determining the plugging thickness of a complex lithology layer based on a simplified lithology combination provided in the fifth embodiment of the present invention is to prepare a roof rock sample by integral molding, heat the roof rock sample to a first set temperature using a first heating device, pressurize the roof rock sample to a first set pressure using a first pressurizing device, and apply stress to the bottom of the roof rock sample step by step from small to large to the first set stress using a first stress device, and stabilize at the temperature, pressure, and stress until the measured values ​​of each sensor are stable, and determine the lower limit of the plugging thickness of the roof rock sample based on the measured values ​​of the sensors and the upper and lower overlapping relationship between the siltstone layer and the mudstone layer. The lower limit of the roof plugging thickness of the shale reservoir is determined by experimental methods based on the simulation of the temperature field, pressure field, and stress field, and the roof plugging conditions of the shale reservoir in situ process are specifically quantified, which can effectively guide production and improve the economic benefits of in-situ exploitation of shale oil and gas.

[0196] The method for determining the sealing thickness of a complex lithology layer based on a simplified lithology combination provided in Example 5 of the present invention determines the vertical superposition relationship of the siltstone layer and the mudstone layer, and the total thickness of the siltstone layer and the total thickness of the mudstone layer according to the lithology vertical distribution characteristics of the overlying strata within a set range, and prepares the roof rock sample in one piece based on the measured properties of the siltstone and mudstone. The prepared synthetic sample takes into account both the properties of mudstone and siltstone, and the vertical superposition relationship between the two, and reasonably simplifies the sample, so that the determination of the lower limit of the sealing thickness of the complex lithology roof with interlayers of mudstone and siltstone can be achieved.

[0197] At present, it is generally believed that only mudstone can effectively seal the shale reservoir during in-situ mining. The method for determining the sealing thickness of complex lithology layers based on simplified lithology combinations provided in Example 5 of the present invention suggests that if the overlying rock layer of the shale reservoir is interlayered siltstone and mudstone, it may also produce a sealing effect during the in-situ mining of the shale reservoir, thereby broadening the exploration prospects of shale oil and gas.

[0198] Embodiment 6

[0199] Embodiment 6 of the present invention provides a specific application of a multi-dimensional and multi-parameter characterization method for a heated rock mass in an in-situ conversion stage of shale oil, comprising the following steps:

[0200] S1: In this example, five wells in the shale oil in-situ conversion development block were selected as evaluation wells, of which two wells were used for systematic coring and detailed lithology evaluation of the proposed heated rock mass and its overlying and underlying rock formations (both with a thickness of not less than 5 m each) ( Figure 7 ). These two coring wells are located in the middle of the development block, at the two ends of the long axis of the rock mass to be heated.

[0201] S2: Use the coring well to establish a logging lithology interpretation model based on the lithology binarization of the organic-rich shale section (organic-rich shale, interlayer), and use the TOC detection data of the coring well system to establish a logging TOC interpretation model. Use the lithology data and TOC data to establish a single-well comprehensive columnar diagram of the organic-rich shale section containing the binary lithology profile and TOC profile. In this embodiment, the lithology data described by the core and the measured TOC data of the two coring wells are used to map ( Figure 7 ), the lithology data and TOC data of three uncored wells were mapped using logging data and logging interpretation models.

[0202] S3: Using samples from the overlying and underlying rock formations of the organic-rich shale section from two coring wells, a simulation experiment was conducted to evaluate the lower limit of the top and bottom plate thickness of the heated rock mass. The core of the experiment is to determine the relationship between the maximum breakthrough pressure of samples of different lithology in the overlying and underlying rock formations of the organic-rich shale section and the thickness of the rock of that lithology. Through the experiment, it is determined that the breakthrough pressure of different lithology samples reaches the corresponding thickness of the top and bottom plates. In this embodiment, the top and bottom plate thicknesses determined by coring well 1 are 6.1m and 3.6m respectively; the top and bottom plate thicknesses determined by coring well 2 are 6.2m and 2.9m respectively. Figure 7 ).

[0203] Through well logging lithology calibration, a well logging lithology interpretation model with different lithologies of the top and bottom plates was established. In the three wells that were not cored, the lithologies of the overlying and underlying strata of the organic-rich shale section were determined through well logging interpretation, and then the thickness of the top and bottom plates of these three wells was determined.

[0204] S4: Use the comprehensive column chart of the organic-rich shale section of the single well including the binary lithology profile and TOC profile established in step S2 to divide the heating formation units. Taking the coring well 1 of this embodiment as an example, the organic-rich shale section (the proposed heating shale section) of the well is divided into three heating formation units. The three have obvious differences in the overall numerical distribution of TOC and lithology combination: the TOC of the T1 section is the highest overall, with no sandstone interlayers; the TOC of the T2 section is second overall, with a small amount of thin sandstone interlayers; the TOC of the T3 section is the lowest overall, with relatively developed sandstone interlayers ( Figure 8 ).

[0205] S5: This example shows the comparison of well connections in the long axis direction of the shale oil in-situ conversion development block ( Fig. 9 ). In the single well columnar diagram of the well-connected section, the binary lithology section and TOC section of the heated rock mass are included. The heated stratigraphic units are divided in the single well, and then the lateral distribution of the heated stratigraphic units and interlayers is determined in turn through well-connected comparison.

[0206] S6: Determine the thickness of the heated rock mass, the TOC single well average, and the top and bottom plate thicknesses in the single well. Using the single well data, determine the thickness of the heated rock mass, the TOC of the heated rock mass, and the planar distribution of the top and bottom plates by interpolation. This embodiment shows the planar distribution diagram of the thickness of the heated rock mass and the thickness of the top plate ( Fig.10 , Fig.11 ).

[0207] S7: Refer to the well-connected profile determined in step S5 and the various plan views determined in step S6, analyze and evaluate the distribution and change trend of various parameters between wells, and establish a well-connected grid map covering the entire shale oil in-situ conversion development block. The grid map shows the three-dimensional spatial distribution of the heating formation units and interlayers in the entire development block ( Fig.12 ).

[0208] Based on the inventive concept of the present invention, the embodiment of the present invention also provides a multi-dimensional and multi-parameter characterization device for heating rock mass in the in-situ conversion stage of shale oil. The structure of the device is as follows: Fig.13 As shown, it includes a binary lithology data acquisition module 131, a heated rock mass division module 132, an interlayer identification module 133, a heated rock mass distribution feature research module 134 and an interlayer single layer thickness lower limit determination module 135;

[0209] Binary lithology data acquisition module 131, used to acquire binary lithology data of organic-rich shale development sections developed in target layers in the studied block, wherein the binary lithology includes organic-rich shale and non-organic-rich shale;

[0210] A heated rock mass division module 132 is used to identify at least one quasi-in-situ conversion section from the organic-rich shale development section according to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, and divide the quasi-in-situ conversion section into at least one heated rock mass according to the distribution characteristics of the binary lithology and the TOC distribution characteristics;

[0211] The interlayer identification module 133 is used to identify the non-organic-rich shale monolayer in the heated rock mass. If the thickness of the non-organic-rich shale monolayer is greater than the lower limit of the monolayer thickness as the interlayer of the proposed in-situ conversion section, the non-organic-rich shale monolayer is identified as an interlayer. The lower limit of the monolayer thickness is predetermined by the interlayer monolayer thickness lower limit determination module 135 based on the average hydrocarbon generation potential value of the organic-rich shale monolayer in the shale layer and a plurality of data pairs including the thickness of the non-organic-rich shale monolayer and its hydrocarbon generation potential value;

[0212] The heated rock mass distribution characteristic research module 134 is used to establish a well-connected grid diagram of the drilled wells, and complete the spatial distribution research of the heated rock mass and the interlayer in each well-connected section in the well-connected grid diagram based on the heated rock mass and interlayer identification results of the single well.

[0213] In some embodiments, the above device further includes a lithology identification model building module 136. If no coring is performed in the target layer after drilling, a binary lithology data acquisition module 131 is used to acquire the binary lithology data of the organic-rich shale development section of the drilled well in the following manner:

[0214] The sensitivity curve of the drilled well is input into the lithology identification model, and the binary lithology data of the organic-rich shale development section is obtained according to the output result of the model. The lithology identification model is pre-established by the lithology identification model establishment module 136 in the following manner:

[0215] The GR value lower limit of the organic-rich shale is determined according to the binary lithology data of the coring section of the target layer of the sample well; the binary lithology data of the coring section and the curve section of the selected sensitivity curve are taken as a sample to establish a sample set; the selected neural network model is trained by using the sample set to establish a lithology recognition model, and the GR value lower limit is input into the lithology recognition model, and the GR value lower limit is used to locate the organic-rich shale development section.

[0216] In some embodiments, the heated rock mass division module 132 is used to divide the quasi-in-situ conversion section into at least one heated rock mass according to the following principles:

[0217] The TOC difference between the heated rock mass in the in-situ conversion section of shale oil and the adjacent heated rock mass meets the first set difference, and / or the lithology combination difference with the adjacent heated rock mass meets the second set difference.

[0218] In some embodiments, the lithology identification model building module 36 is used to obtain the binary lithology data of the coring section of the target layer of the sample well in the following manner:

[0219] According to the thin section identification data of the coring section of the target layer of the sample well, the lithology description data in the core description data is corrected to obtain preliminary lithology data, and the preliminary lithology data includes mud shale; according to the TOC detection data, the mud shale in the preliminary lithology data whose TOC value is greater than the preset organic-rich shale TOC lower limit is determined as organic-rich shale, and the binary lithology data of the coring section is obtained.

[0220] In some embodiments, the lithology identification model building module 136 is used to extract the lithology and GR value of the sampling points with thin section identification data and TOC detection data based on the binary lithology data and GR curve of the sample well; according to the lithology and GR values ​​of multiple sampling points, the lower limit of the GR value of organic-rich shale is statistically obtained.

[0221] In some embodiments, the interlayer single layer thickness lower limit determination module 135 is used to predetermine the single layer thickness lower limit of the interlayer as the proposed in-situ conversion section in the following manner:

[0222] According to each of the data pairs, a sample point is obtained, including the thickness of the non-organic-rich shale single layer and the ratio of the hydrocarbon generation potential value to the average hydrocarbon generation potential value of the organic-rich shale single layer; the sample point is projected into a coordinate system, and a trend line is obtained by fitting; according to the trend line, the ratio of the hydrocarbon generation potential value to the average hydrocarbon generation potential value of the organic-rich shale single layer is determined to be the thickness of the non-organic-rich shale single layer corresponding to the set ratio; and the thickness is determined as the lower limit of the single layer thickness of the non-organic-rich shale single layer as the interlayer of the pseudo-in-situ conversion section.

[0223] In some embodiments, the interlayer single layer thickness lower limit determination module 135 is used to obtain the average hydrocarbon generation potential value of the organic-rich shale single layer in the shale layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value in the following manner:

[0224] According to the centimeter-level core description data of continuous coring sections in the shale layer, a quasi-in-situ conversion section is identified from the coring section, the identified quasi-in-situ conversion section is divided into multiple units according to the sedimentary cycle, the type of each unit is determined according to the thickness ratio of the quasi-in-situ conversion section, and at least one unit of each type is screened; a millimeter-level binary lithological description is performed on the screened units, and the units are divided into multiple organic-rich shale monolayers and non-organic-rich shale monolayers according to the description results, rock samples are cut from the monolayers, and the hydrocarbon generation potential values ​​of the rock samples are determined through pyrolysis tests; and the average value of the hydrocarbon generation potential values ​​of the organic-rich shale monolayers and multiple data pairs including the thickness of the non-organic-rich shale monolayers and their hydrocarbon generation potential values ​​are statistically obtained.

[0225] In some embodiments, the interlayer single layer thickness lower limit determination module 135 is used to:

[0226] Each unit is classified into one of the following types:

[0227] The thickness ratio of the proposed in-situ conversion section is less than 1%, the thickness ratio of the proposed in-situ conversion section is not less than 1% and not more than 5%, the thickness ratio of the proposed in-situ conversion section is greater than 5% and not more than 10%, and the thickness ratio of the proposed in-situ conversion section is greater than 10%.

[0228] In some embodiments, the heated rock mass distribution characteristics research module 134 is further used to:

[0229] For each heated rock mass, the heated rock mass thickness, interlayer thickness and interlayer thickness ratio of a single well are statistically analyzed, and the heated rock mass thickness plane map, interlayer thickness plane map and interlayer thickness ratio plane map are drawn by interpolation method.

[0230] Regarding the device in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

[0231] Based on the inventive concept of the present invention, an embodiment of the present invention further provides a computer storage medium, in which computer executable instructions are stored. When the computer executable instructions are executed by a processor, the above-mentioned method for identifying heated rock interlayers in the in-situ conversion section of shale oil is implemented.

[0232] Based on the inventive concept of the present invention, an embodiment of the present invention also provides a server, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the above-mentioned method for identifying heated rock interlayers in the in-situ conversion section of shale oil when executing the program.

[0233] Unless otherwise specifically stated, terms such as processing, computing, calculating, determining, displaying, etc. may refer to the actions and / or processes of one or more processing or computing systems, or similar devices, which operate and convert data represented as physical (e.g., electronic) quantities within registers or memories of a processing system into other data similarly represented as physical quantities within memories, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals may be represented using any of a variety of different techniques and methods. For example, data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description may be represented by voltages, currents, electromagnetic waves, magnetic fields or particles, light fields or particles, or any combination thereof.

[0234] It should be understood that the specific order or hierarchy of steps in the disclosed process is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of protection of the present disclosure. The attached method claims present the elements of the various steps in an exemplary order and are not intended to be limited to the specific order or hierarchy described.

[0235] In the above detailed description, various features are grouped together in a single embodiment to simplify the disclosure. This method of disclosure should not be interpreted as reflecting an intention that an embodiment of the claimed subject matter requires more features than those set forth in each claim. On the contrary, as reflected in the appended claims, the invention is in a state of having less than all the features of the disclosed individual embodiments. Therefore, the appended claims are hereby expressly incorporated into the detailed description, with each claim standing on its own as a separate preferred embodiment of the invention.

[0236] Those skilled in the art will also appreciate that the various illustrative logic blocks, modules, circuits, and algorithmic steps described in conjunction with the embodiments herein can all be implemented as electronic hardware, computer software, or a combination thereof. In order to clearly illustrate the interchangeability between hardware and software, various illustrative components, blocks, modules, circuits, and steps are generally described above around their functions. Whether such functions are implemented as hardware or software depends on specific applications and the design constraints imposed on the entire system. A skilled person can implement the described functions in an alternative manner for each specific application, but such implementation decisions should not be interpreted as departing from the scope of protection of the present disclosure.

[0237] The steps of the method or algorithm described in conjunction with the embodiments herein may be directly embodied as hardware, a software module executed by a processor, or a combination thereof. The software module may be located in a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a mobile disk, a CD-ROM, or any other form of storage medium well known in the art. An exemplary storage medium is connected to the processor so that the processor can read information from the storage medium and can write information to the storage medium. Of course, the storage medium may also be an integral part of the processor. The processor and the storage medium may be located in an ASIC. The ASIC may be located in a user terminal. Of course, the processor and the storage medium may also be present in a user terminal as discrete components.

[0238] For software implementation, the techniques described in this application can be implemented with modules (e.g., procedures, functions, etc.) that perform the functions described in this application. These software codes can be stored in a memory unit and executed by a processor. The memory unit can be implemented within the processor or outside the processor. In the latter case, it is coupled to the processor in a communication manner via various means, which are well known in the art.

[0239] The above description includes examples of one or more embodiments. Of course, it is impossible to describe all possible combinations of components or methods for the purpose of describing the above embodiments, but it should be recognized by those skilled in the art that the various embodiments can be further combined and arranged. Therefore, the embodiments described herein are intended to cover all such changes, modifications and variations that fall within the scope of protection of the appended claims. In addition, with respect to the term "comprising" used in the specification or claims, the word is covered in a manner similar to the term "including", just as "including," explained as a transitional word in the claims. In addition, any term "or" used in the specification of the claims is intended to represent "non-exclusive or". The terms "first" and "second" are used for descriptive purposes only and are not to be understood as indicating or implying relative importance.

Claims

1. A multi-dimensional and multi-parameter characterization method for heating rock mass in the in-situ conversion stage of shale oil, characterized in that: include: Obtaining binary lithology data of organic-rich shale development sections developed in target layers in wells drilled in the study area, wherein the binary lithology data includes organic-rich shale and non-organic-rich shale; According to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, at least one pseudo-in-situ conversion section is identified from the organic-rich shale development section, and according to the distribution characteristics of the binary lithology and the TOC distribution characteristics, the pseudo-in-situ conversion section is divided into at least one heated rock mass; Identify a non-organic-rich shale monolayer in the heated rock mass, and if the thickness of the non-organic-rich shale monolayer is greater than a lower limit of the monolayer thickness as an interlayer of the proposed in-situ conversion stage, identify the non-organic-rich shale monolayer as an interlayer, wherein the lower limit of the monolayer thickness is predetermined based on an average value of hydrocarbon generation potential values ​​of the organic-rich shale monolayer in the shale layer and a plurality of data pairs including the thickness of the non-organic-rich shale monolayer and its hydrocarbon generation potential value; A well-connected grid diagram of the drilled wells is established, and based on the identification results of the heated rock mass and interlayer of a single well, a spatial distribution study of the heated rock mass and the interlayer therein of each well-connected section in the well-connected grid diagram is completed.

2. The method according to claim 1, characterized in that If no coring is done in the target layer, the binary lithology data of the organic-rich shale development section can be obtained by the following method: The sensitivity curve of the drilled well is input into the lithology identification model, and the binary lithology data of the organic-rich shale development section is obtained according to the output result of the model. The lithology identification model is pre-established in the following way: The GR value lower limit of the organic-rich shale is determined according to the binary lithology data of the coring section of the target layer of the sample well; the binary lithology data of the coring section and the curve section of the selected sensitive curve are taken as a sample to establish a sample set; the selected neural network model is trained by using the sample set to establish a lithology recognition model, and the GR value lower limit is input into the lithology recognition model, and the GR value lower limit is used to locate the organic-rich shale development section.

3. The method according to claim 2, characterized in that The model output result is obtained by the lithology identification model in the following way: Locate the organic-rich shale development section according to the GR value lower limit and the GR curve of the drilled well; According to the neural network learning result of the corresponding sensitive curve segment of the organic-rich shale development segment, the binary lithology data thereof is determined to obtain the result for output.

4. The method according to claim 2, characterized in that: The binary lithology data of the core section of the target layer of the sample well is obtained by the following method: According to the thin section identification data of the coring section of the target layer of the sample well, the lithology description data in the core description data is corrected to obtain preliminary lithology data, wherein the preliminary lithology data includes mud shale; According to the TOC detection data, the mud shale with a TOC value greater than a preset lower limit of TOC of organic-rich shale in the preliminary lithology data is determined as organic-rich shale, and the binary lithology data of the coring section is obtained.

5. The method according to claim 4, characterized in that Determining the lower limit of the GR value of organic-rich shale includes: Based on the binary lithology data and GR curve of the sample well, the lithology and GR value of the sampling point with thin section identification data and TOC detection data are extracted; According to the lithology and GR values ​​of multiple sampling points, the lower limit of the GR value of organic-rich shale was obtained statistically.

6. The method according to claim 1, characterized in that The step of dividing the quasi-in-situ conversion section into at least one heated rock mass comprises: The quasi-in-situ conversion section is divided into at least one heated rock mass according to the following principles: The TOC difference between the heated rock mass and the adjacent heated rock mass satisfies a first set difference, and / or the lithology combination difference between the heated rock mass and the adjacent heated rock mass satisfies a second set difference.

7. The method according to claim 6, characterized in that The first setting difference includes an overall TOC value difference and / or an overall TOC curve morphology difference; The second set difference includes a difference in the number of non-organic-rich shale layers and / or a difference in the thickness of the non-organic-rich shale layers.

8. The method according to claim 1, characterized in that The lower limit of the thickness of the non-organic-rich shale monolayer as the interlayer of the proposed in-situ conversion section is predetermined by the following method: According to each of the data pairs, a sample point is obtained, which includes the ratio of the thickness and hydrocarbon generation potential value of the non-organic-rich shale single layer to the average value of the hydrocarbon generation potential value of the organic-rich shale single layer; The sample points are projected into a coordinate system, and a trend line is obtained by fitting. According to the trend line, the ratio of the hydrocarbon generation potential value to the average hydrocarbon generation potential value of the organic-rich shale single layer is determined as the thickness of the non-organic-rich shale single layer corresponding to the set ratio, and the thickness is determined as the lower limit of the single layer thickness of the non-organic-rich shale single layer as the interlayer of the pseudo-in-situ conversion section.

9. The method according to claim 2, characterized in that: The average value of hydrocarbon generation potential of a single layer of organic-rich shale in the shale layer and a plurality of data pairs including the thickness of a single layer of non-organic-rich shale and its hydrocarbon generation potential are obtained by the following method: According to the binary lithology data of the core section of the target layer of the sample well and the upper limit of the proportion of non-organic-rich shale in the in-situ conversion section, the pseudo-in-situ conversion section is identified from the core section, the identified pseudo-in-situ conversion section is divided into a plurality of units according to the sedimentary cycle, the type of each unit is determined according to the thickness ratio of the pseudo-in-situ conversion section, and at least one unit is selected from each type of unit; Carry out millimeter-level binary lithology description on the selected units, divide the units into multiple organic-rich shale monolayers and non-organic-rich shale monolayers according to the description results, cut rock samples from the monolayers, and determine the hydrocarbon generation potential of the rock samples through pyrolysis tests; The average value of the hydrocarbon generation potential value of the organic-rich shale single layer and multiple data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value are obtained by statistics.

10. The method according to claim 9, characterized in that The type of each unit is determined according to the thickness ratio of the proposed in-situ conversion section, including: Each unit is classified into one of the following types: The thickness ratio of the proposed in-situ conversion section is less than 1%, the thickness ratio of the proposed in-situ conversion section is not less than 1% and not more than 5%, the thickness ratio of the proposed in-situ conversion section is greater than 5% and not more than 10%, and the thickness ratio of the proposed in-situ conversion section is greater than 10%.

11. The method according to claim 1, characterized in that: It also includes, for each heated rock mass, counting the heated rock mass thickness, interlayer thickness and interlayer thickness ratio of a single well, and drawing a heated rock mass thickness plane map, an interlayer thickness plane map and an interlayer thickness ratio plane map by interpolation method.

12. The method according to any one of claims 1 to 11, characterized in that: The hydrocarbon generation potential value is the sum of free hydrocarbons S1 and pyrolysis hydrocarbons S2 per unit mass of rock.

13. The method according to any one of claims 1 to 11, characterized in that: The upper limit of the proportion of non-organic-rich shale in the in-situ conversion stage is 20%.

14. A multi-dimensional and multi-parameter characterization device for heating rock mass in the in-situ conversion stage of shale oil, characterized in that: The device comprises a binary lithology data acquisition module, a heated rock mass division module, an interlayer identification module, a heated rock mass distribution feature research module and an interlayer single layer thickness lower limit determination module; The binary lithology data acquisition module is used to acquire binary lithology data of the organic-rich shale development section developed in the target layer in the studied block, wherein the binary lithology data includes organic-rich shale and non-organic-rich shale; The heated rock mass division module is used to identify at least one pseudo-in-situ conversion section from the organic-rich shale development section according to the set upper limit of the proportion of non-organic-rich shale in the in-situ conversion section and the binary lithology data, and divide the pseudo-in-situ conversion section into at least one heated rock mass according to the distribution characteristics of the binary lithology and the TOC distribution characteristics; The interlayer identification module is used to identify a non-organic-rich shale single layer in the heated rock mass. If the thickness of the non-organic-rich shale single layer is greater than the lower limit of the single layer thickness of the interlayer in the proposed in-situ conversion section, the non-organic-rich shale single layer is identified as an interlayer. The lower limit of the single layer thickness is predetermined by the interlayer single layer thickness lower limit determination module based on the average hydrocarbon generation potential value of the organic-rich shale single layer in the shale layer and a plurality of data pairs including the thickness of the non-organic-rich shale single layer and its hydrocarbon generation potential value; The heated rock mass distribution characteristic research module is used to establish a well-connected grid diagram of drilled wells, and complete the spatial distribution research of the heated rock mass and the interlayer body therein in each well-connected section in the well-connected grid diagram based on the heated rock mass and interlayer identification results of a single well.

15. A computer storage medium, characterized in that The computer storage medium stores computer executable instructions, which, when executed by a processor, implement the multi-dimensional and multi-parameter characterization method for heated rock mass in the in-situ conversion stage of shale oil as described in any one of claims 1 to 13.

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