Method and device for determining effective porosity of shale oil reservoir

Abstract

The invention relates to the technical field of oil exploration, and provides a shale oil reservoir effective porosity determination method and device. The method comprises the following steps: acquiring target logging information to obtain the stratum density of a target stratum and the total organic carbon content of kerogen; judging whether the target logging information comprises element full-spectrum logging information or not; if yes, normalization analysis is carried out on the element full-spectrum logging information, and if not, combinatorial analysis is carried out on preset logging information in the target logging information, so that inorganic framework mineral component content information and clay content of the target stratum are obtained; calculating the density of the mixed inorganic mineral skeleton according to the mineral component content information of the inorganic skeleton; and calculating the effective porosity of the target stratum according to the stratum density, the total organic carbon content of kerogen, the mixed inorganic mineral skeleton density and the clay content. According to the embodiment of the invention, the influence of organic and inorganic mineral skeletons on the porosity can be considered, so that the calculation precision of the effective porosity of the shale oil reservoir is improved.

Description

TECHNICAL FIELD

[0001] The present specification relates to the technical field of oil exploration, and in particular, to a shale oil reservoir effective porosity determination method and device. BACKGROUND

[0002] In recent years, shale oil has increasingly become a key field of oil exploration and development, and accurate quantitative characterization of the effective porosity of shale oil reservoirs is of great significance for shale oil reservoir quality classification and evaluation and accurate assessment of shale oil resource scale. Existing technologies often use a variable matrix parameter method to calculate the porosity of complex lithology reservoirs, but this method only considers the influence of inorganic mineral components such as clay, quartz, feldspar, dolomite, and calcite. The shale oil formation matrix not only includes common inorganic minerals such as clay, quartz, feldspar, calcite, and dolomite, but also includes organic minerals such as kerogen, which have the characteristics of low density (1.5 g / cm 3 around). The matrix parameters have the characteristics of strong heterogeneity change in the continuous depth range. Without nuclear magnetic resonance logging data, how to consider the influence of organic and inorganic mineral matrixes on porosity and use density logging data to characterize the effective porosity of shale oil reservoirs with complex lithology characteristics is a technical problem that needs to be solved urgently. Therefore, there is an urgent need for a shale oil reservoir effective porosity determination method and device that considers the influence of organic and inorganic mineral matrixes on porosity to improve the calculation accuracy of the effective porosity of shale oil reservoirs without nuclear magnetic resonance logging data. SUMMARY

[0003] In view of the fact that existing technologies often use a variable matrix parameter method to calculate the porosity of complex lithology reservoirs, but this method only considers the influence of inorganic mineral components such as clay, quartz, feldspar, dolomite, and calcite. The shale oil formation matrix not only includes common inorganic minerals such as clay, quartz, feldspar, calcite, and dolomite, but also includes organic minerals such as kerogen, which have the characteristics of low density (1.5 g / cm 3 around). The matrix parameters have the characteristics of strong heterogeneity change in the continuous depth range, the present scheme is proposed to overcome the above problems or at least partially solve the above problems.

[0004] In one aspect, some embodiments of the present specification aim to provide a shale oil reservoir effective porosity determination method, which comprises:

[0005] obtaining target logging data;

[0006] using the target logging data to obtain the formation density and total organic carbon content of kerogen of the target formation;

[0007] determining whether the target logging data includes element full spectrum logging data;

[0008] If the element full spectrum logging data is included, the element full spectrum logging data is normalized and analyzed to obtain the inorganic framework mineral component content information and the clay content of the target formation;

[0009] If the element full spectrum logging data is not included, preset logging data in the target logging data is combined and analyzed to obtain the inorganic framework mineral component content information and the clay content of the target formation;

[0010] According to the inorganic framework mineral component content information, the corresponding mixed inorganic mineral framework density is calculated;

[0011] The formation density, the total organic carbon content of kerogen, the mixed inorganic mineral framework density and the clay content are used to calculate the effective porosity of the target formation.

[0012] Further, the formation density and the total organic carbon content of kerogen of the target formation are obtained by using the target logging data, including:

[0013] According to the natural gamma-ray spectral logging data in the target logging data, the total organic carbon content of kerogen is calculated;

[0014] The target formation density is obtained by using the target logging data.

[0015] Further, the total organic carbon content of kerogen is calculated according to the natural gamma-ray spectral logging data in the target logging data, including:

[0016] According to the uranium content curve in the natural gamma-ray spectral logging data, the total organic carbon content of kerogen is calculated by using the following formula:

[0017]

[0018] In the formula, TOC is the total organic carbon content of kerogen, and U is the uranium content. k

[0019] Further, if the element full spectrum logging data is included, the element full spectrum logging data is normalized and analyzed to obtain the inorganic framework mineral component content information and the clay content of the target formation, including:

[0020] According to the element full spectrum logging data, the yields of different elements are obtained, and according to the yields of different elements, a normalization analysis model is constructed based on the oxide index and the detection sensitivity factor corresponding to different elements;

[0021] According to the yields of different elements and the normalization analysis model, the contents of different elements are calculated;

[0022] ​By using the element-mineral conversion coefficient matrix, the contents of the different elements are converted to obtain the content information of inorganic framework mineral components and clay content.

[0023] Furthermore, the preset logging data includes at least one or more of the following: spontaneous potential logging data, natural gamma logging data, sonic logging data, neutron logging data, density logging data, lateral logging data, induction logging data, and formation dip logging data.

[0024] Furthermore, if the full-spectrum elemental logging data is not included, the preset logging data in the target logging data are combined and analyzed to obtain the content information of inorganic framework mineral components and clay content of the target formation, including:

[0025] Based on the preset logging data, multiple corresponding logging response equations are obtained;

[0026] Based on the simultaneous combination of the multiple logging response equations, the content information of inorganic framework mineral components and clay content of the target formation are calculated.

[0027] Further, based on the inorganic framework mineral component content information, the corresponding mixed inorganic mineral framework density is calculated, including:

[0028] Based on the inorganic framework mineral component content information, the corresponding mixed inorganic mineral framework density is calculated using the following formula:

[0029] ρ ma =∑(V mai ·ρ mai ), i = 1, 2, ..., n

[0030] Where, ρ ma For the density of the mixed inorganic mineral framework, V mai ρ represents the volume content of the i-th inorganic framework mineral component. mai Let be the density of the i-th inorganic framework mineral component, n be the total number of inorganic framework mineral components, and i be the ordinal number of the inorganic framework mineral component.

[0031] Furthermore, using the formation density, total organic carbon content of kerogen, density of the mixed inorganic mineral framework, and clay content, the effective porosity of the target formation is calculated, including:

[0032] Obtain the density parameters corresponding to the formation density, total organic carbon content of kerogen, and clay content; the density parameters include formation fluid density, kerogen density, and wet clay density.

[0033] Based on the density parameter, the effective porosity of the target formation is calculated according to the following formula by using the formation volume density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content in the formation density:

[0034]

[0035] wherein φ is the effective porosity, ρ is the formation volume density, ρ is the mixed inorganic mineral framework density, ρ is the formation fluid density, V is the clay content, ρ is the wet clay density, TOC is the total organic carbon content of kerogen, and ρ is the kerogen density. e b ma f sh sh k k

[0036] In another aspect, some embodiments of the present specification also provide an effective porosity determination device for a shale oil reservoir, the device comprising:

[0037] a receiving module configured to acquire target logging data;

[0038] a determination module configured to obtain the formation density and the total organic carbon content of kerogen of a target formation by using the target logging data;

[0039] a judgment module configured to determine whether the target logging data comprises element full spectrum logging data;

[0040] a first analysis module configured to, if the element full spectrum logging data is included, perform normalization analysis on the element full spectrum logging data to obtain inorganic framework mineral component content information and clay content of the target formation;

[0041] a second analysis module configured to, if the element full spectrum logging data is not included, perform combined analysis on preset logging data in the target logging data to obtain inorganic framework mineral component content information and clay content of the target formation;

[0042] a mixed inorganic mineral framework density calculation module configured to calculate the corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information;

[0043] an effective porosity calculation module configured to calculate the effective porosity of the target formation by using the formation density, the total organic carbon content of kerogen, the mixed inorganic mineral framework density and the clay content.

[0044] ​​​​​​​​In another aspect, some embodiments of the present specification also provide a computer device, comprising a memory, a processor, and a computer program stored on the memory, which, when executed by the processor, performs the instructions of the above method.

[0045] In another aspect, some embodiments of the present specification also provide a computer storage medium having a computer program stored thereon, which, when executed by a processor of a computer device, performs the instructions of the above method.

[0046] In another aspect, some embodiments of the present specification also provide a computer program product, comprising a computer program, which, when executed by a processor of a computer device, performs the instructions of the above method.

[0047] The one or more technical solutions provided by some embodiments of the present specification have at least the following technical effects:

[0048] The embodiments of the present specification first automatically acquire target logging data to obtain the formation density and total organic carbon content of the target formation, and then analyze the inorganic framework mineral component content information and clay content of the target formation according to whether the target logging data includes element full spectrum logging data. Since the element full spectrum logging data can more accurately analyze the inorganic framework mineral component content information and clay content, when the target logging data includes the element full spectrum logging data, the element full spectrum logging data is normalized and analyzed, and when the target logging data does not include the element full spectrum logging data, the preset logging data (usually conventional logging data) in the target logging data is combined and analyzed to accurately determine the inorganic framework mineral component content information and clay content of the target formation. Then, the corresponding mixed inorganic mineral framework density is calculated according to the inorganic framework mineral component content information to approximate the mixed inorganic mineral framework density data in the real formation as much as possible, and the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density, and clay content are comprehensively considered. In the absence of nuclear magnetic resonance logging data, based on the influence of organic and inorganic mineral framework on porosity in the real formation, the effective porosity of the shale oil reservoir is accurately and efficiently calculated.

[0049] The above description is only a summary of some technical solutions of the present specification. In order to enable a clearer understanding of the technical means of some embodiments of the present specification, which can be implemented according to the content of the specification, and in order to make the above and other purposes, features and advantages of some embodiments of the present specification more obvious and easy to understand, the following specific embodiments of some embodiments of the present specification are described. BRIEF DESCRIPTION OF DRAWINGS

[0050] In order to more clearly illustrate the technical solutions in the embodiments of the present specification or the prior art, the drawings needed to be used in the embodiment or prior art description will be briefly introduced as follows. Obviously, the drawings in the following description only represent some embodiments described in the present specification, and for those skilled in the art, other drawings can also be obtained from these drawings without creative labor. In the drawings:

[0051] Figure 1 An implementation system schematic diagram of a method for determining effective porosity of a shale oil reservoir is shown in some embodiments of the present specification;

[0052] Figure 2 A flow chart of a method for determining effective porosity of a shale oil reservoir is shown in some embodiments of the present specification;

[0053] Figure 3 A comparison schematic diagram of logging parameters and effective porosity in some embodiments of the present specification;

[0054] Figure 4 A structural schematic diagram of a device for determining effective porosity of a shale oil reservoir is shown in some embodiments of the present specification;

[0055] Figure 5 A structural schematic diagram of a computer device provided in some embodiments of the present specification.

[0056]

Explanation of reference numerals

[0057] 101, terminal;

[0058] 102, server;

[0059] 401, receiving module;

[0060] 402, determining module;

[0061] 403, judging module;

[0062] 404, first analysis module;

[0063] 405, second analysis module;

[0064] 406, mixed inorganic mineral framework density calculation module;

[0065] 407, effective porosity calculation module;

[0066] 502, computer device;

[0067] 504, processor;

[0068] 506, memory;

[0069] 508, drive mechanism;

[0070] 510, input / output interface;

[0071] 512, input device;

[0072] 514, output device;

[0073] 516, presentation device;

[0074] 518, graphical user interface;

[0075] 520, network interface;

[0076] 522, communication link;

[0077] 524, communication bus. DETAILED DESCRIPTION

[0078] In order to make the technical personnel in the technical field better understand the technical solutions in the specification, the technical solutions in the specification embodiments will be described clearly and completely in the following combined with the drawings in some embodiments of the specification. Obviously, the described embodiments are only some of the embodiments of the specification, not all. Based on some embodiments in the specification, all other embodiments obtained by those of ordinary skill in the art without creative labor should be within the scope of protection of the specification.

[0079] It should be noted that the terms "first", "second", etc. in the specification and claims and the above-mentioned drawings are used to distinguish similar objects, and do not necessarily describe a specific order or sequence. It should be understood that the data used in this way can be interchanged under appropriate circumstances, so that the embodiments of the specification described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "include" and "have" and any variations thereof are intended to cover non-exclusive inclusion, for example, a process, method, device, product or equipment that includes a series of steps or units does not necessarily limit to those steps or units clearly listed, but can include other steps or units that are not clearly listed or inherent to these processes, methods, products or equipment.

[0080] It should be noted that in the embodiments of the specification, some software, components, models, etc. in the industry may be mentioned, which should be considered as exemplary, and the purpose is only to illustrate the feasibility of the technical solution in the application, but it does not mean that the applicant has or will necessarily use the scheme.

[0081] It should be noted that in the embodiments of this specification, certain software, components, models and other existing solutions in the industry may be mentioned. These should be regarded as exemplary and are only intended to illustrate the feasibility of implementing the technical solution of this application. However, they do not mean that the applicant has used or necessarily used the solution.

[0082] It should be noted that the acquisition, storage, use, and processing of data in the technical solution of this application all comply with the relevant provisions of relevant laws and regulations.

[0083] like Figure 1 The diagram illustrates an implementation system for a method of determining the effective porosity of a shale oil reservoir according to an embodiment of the present invention. The system may include a terminal 101 and a server 102. The terminal 101 and server 102 communicate via a network, which may include a Local Area Network (LAN), a Wide Area Network (WAN), the Internet, or a combination thereof, and is connected to a website, user equipment (e.g., computing devices), and a backend system. Personnel can send a request to the server 102 to determine the effective porosity of the shale oil reservoir via the terminal 101. Upon receiving the request, the server 102 retrieves target well logging data from its database for calculation and processing, obtains the calculation result, and sends the result back to the terminal 101 so that personnel can conduct subsequent oil exploration operations based on the calculation result.

[0084] In the embodiments of this specification, the server 102 may be an independent physical server, a server cluster or distributed system composed of multiple physical servers, or a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, content delivery networks (CDN), and big data and artificial intelligence platforms.

[0085] In an optional embodiment, terminal 101 may be an electronic device, including but not limited to self-service terminal equipment, desktop computers, laptops, etc. Optionally, the operating system running on the electronic device may include, but is not limited to, Android, iOS, Linux, Windows, etc. Of course, terminal 101 is not limited to the aforementioned physical electronic devices; it may also be software running on the aforementioned electronic devices.

[0086] In addition, it should be noted that, Figure 1 The example shown is merely one application environment provided by this disclosure. In practical applications, it may include multiple terminals 101, and this specification does not impose any restrictions.

[0087] Figure 2 is a flow chart of a method for determining effective porosity of a shale oil reservoir according to an embodiment of the present application. The present specification provides method operation steps as described in the embodiments or flow charts, but can include more or less steps than those shown or described. The steps shown in the embodiments are merely one way of executing the steps and are not necessarily the only way of executing the steps. In actual system or device product implementation, the method steps can be executed in sequence or in parallel as shown in the embodiments or drawings. Specifically, as shown in the flow chart, the method can include: Figure 2

[0088] S201: obtaining target logging data;

[0089] It can be understood that in some embodiments, logging, also known as geophysical logging, is a method of measuring geophysical parameters by using the electrochemical properties, electrical conductivity properties, acoustic properties, radioactivity, and other geophysical properties of rock formations. The target logging data can include natural gamma-ray spectral logging data, element full-spectrum logging data, conventional logging data, etc. Through the target logging data, stratigraphic sequence division and calibration, fine geological structure of oil and gas reservoirs, and fault research can be performed, thereby realizing subsequent calculation of the effective porosity of the shale oil reservoir.

[0090] S202: obtaining formation density and total organic carbon content of kerogen of a target formation by using the target logging data;

[0091] It can be understood that in some embodiments, when calculating the effective porosity of the shale oil reservoir, the formation density and organic framework information (i.e., total organic carbon content of kerogen) are first determined according to the target logging data. The target logging data is used to obtain the formation density and total organic carbon content of kerogen of the target formation, including:

[0092] calculating the total organic carbon content of kerogen according to the natural gamma-ray spectral logging data in the target logging data;

[0093] obtaining the target formation density by using the target logging data.

[0094] Specifically, in some embodiments, the total organic carbon content of kerogen is calculated according to the natural gamma-ray spectral logging data in the target logging data, including:

[0095] the total organic carbon content of kerogen is calculated according to the uranium content curve in the natural gamma-ray spectral logging data by using the following formula:

[0096]

[0097] wherein, TOC k is the total organic carbon content of kerogen, and U is the uranium content.​

[0098] It can be understood that, in some embodiments, the total organic carbon content of the kerogen can be quickly and accurately estimated by the uranium content curve, and the formation density is obtained according to the density logging data in the target logging data.

[0099] S203: determining whether the target logging data includes element full spectrum logging data;

[0100] It can be understood that, in some embodiments, the inorganic framework mineral component content information and the clay content obtained by analyzing the element full spectrum logging data are more accurate than those obtained by the element full spectrum logging data. However, in the actual evaluation of the effective porosity of the shale oil reservoir, the target logging data does not always include the element full spectrum logging data, so it is necessary to judge the target logging data.

[0101] S204: if the element full spectrum logging data is included, performing normalization analysis on the element full spectrum logging data to obtain the inorganic framework mineral component content information and the clay content of the target formation;

[0102] It can be understood that, in some embodiments, if the element full spectrum logging data is included, the normalization analysis is performed on the element full spectrum logging data to obtain the inorganic framework mineral component content information and the clay content of the target formation, including:

[0103] According to the yield of different elements obtained from the element full spectrum logging data, and according to the yield of different elements, based on the oxide index and the detection sensitivity factor corresponding to different elements, a normalization analysis model is constructed;

[0104] According to the yield of different elements and the normalization analysis model, the content of different elements is calculated;

[0105] The content of different elements is converted by using the element-mineral conversion coefficient matrix to obtain the inorganic framework mineral component content information and the clay content.

[0106] Specifically, in some embodiments, the inorganic framework mineral component includes quartz, feldspar, calcite, dolomite, etc. It should be noted that clay also belongs to inorganic matter. In addition to the organic framework, the inorganic framework mineral component content information and the clay content are also considered in the shale oil reservoir effective porosity in the embodiments of the present application. First, the yield of different elements is obtained according to the element full spectrum logging data (the yield is a kind of relative yield information), and based on the oxide index and the detection sensitivity factor corresponding to different elements, the normalization analysis model is established by using the following formula:

[0107]

[0108] wherein F is a normalization analysis model, X i is an oxide index of element i, Y i is a relative yield of element i, S i is a detection sensitivity factor of element i.

[0109] Then, according to the yield of different elements and the normalization analysis model, the content of different elements is calculated by using the following formula:

[0110]

[0111] wherein W i is the content of element i. The content is used to measure the weight of the element.

[0112] Finally, the content of different elements is converted to obtain the inorganic framework mineral component content information and clay content by using the element-mineral conversion coefficient matrix based on the following formula:

[0113] [M] = [C] -1 [E]

[0114] In the formula, [M] is the matrix of inorganic framework mineral component content information and clay content, [C] is the matrix of element-mineral conversion coefficient, and [E] is the matrix of element content. Through the above method of calculating the inorganic framework mineral component content information and clay content, the inorganic framework mineral component content information and clay content can be quickly and accurately evaluated.

[0115] S205: If the element full spectrum logging data is not included, the preset logging data in the target logging data is combined and analyzed to obtain the inorganic framework mineral component content information and clay content of the target formation;

[0116] It can be understood that in some embodiments, the preset logging data can be understood as conventional logging data, which at least includes one or more of natural potential logging data, natural gamma logging data, acoustic logging data, neutron logging data, density logging data, lateral logging data, induction logging data, and formation dip logging data.

[0117] In some embodiments, if the element full spectrum logging data is not included, the preset logging data in the target logging data is combined and analyzed to obtain the inorganic framework mineral component content information and clay content of the target formation, including:

[0118] According to the preset logging data, a plurality of logging response equations corresponding thereto are obtained;

[0119] The inorganic framework mineral component content information and clay content of the target formation are calculated by simultaneously combining the plurality of logging response equations.

[0120] Specifically, in some embodiments, if the target logging data does not include element spectroscopy logging data, it is necessary to perform combined analysis on the preset logging data, and solve the inorganic framework mineral component content information and the clay content of the target formation by simultaneously solving multiple logging response equations corresponding to the preset logging data. These logging response equations include equations of different types of logging responses such as acoustic wave, neutron, density, natural gamma, resistivity, etc. In each type of logging response equation, the logging response value of the formation of this type is known, the logging response value of each mineral component of this type is known, and the inorganic framework mineral component content information and the clay content are unknown.

[0121] For example, the acoustic logging response equation can be simply described as:

[0122] AC = f1 (AC 石英 V 石英 , AC 长石 V 长石 , AC 方解石 V 方解石 , AC 白云石 V 白云石 , AC 粘土含量 V 粘土含量 )

[0123] Wherein, AC is the acoustic logging value of the formation, f1 is the mapping relationship corresponding to the acoustic logging response equation, AC 石英 is the acoustic logging value of the quartz mineral, AC 长石 is the acoustic logging value of the feldspar mineral, AC 方解石 is the acoustic logging value of the calcite mineral, AC 白云石 is the acoustic logging value of the dolomite mineral, AC 粘土含量 is the acoustic logging value of the clay mineral, V 石英 is the quartz content, V 长石 is the feldspar content, V 方解石 is the calcite content, V 白云石 is the dolomite content, and V 粘土 is the clay content.

[0124] The neutron logging response equation can be simply described as:

[0125] CNL = f2 (CNL 石英 V 石英 , CNL 长石 V 长石 , CNL 方解石 V 方解石 , CNL 白云石 V 白云石 , CNL 粘土含量 V 粘土含量 )

[0126] Where CNL is the neutron logging value of the formation, f2 is the mapping relationship corresponding to the neutron logging response equation, and CNL 石英 CNL represents the neutron logging value for quartz minerals. 长石 CNL represents the neutron logging value for feldspar minerals. 方解石 CNL represents the neutron logging value for calcite minerals. 白云石 CNL represents the neutron logging value for dolomite minerals. 粘土含量 V represents the neutron logging value for clay minerals. 石英 V represents the quartz content. 长石 Feldspar content, V 方解石 For calcite content, V 白云石 Dolomite content, V 粘土 This represents the clay content.

[0127] In some embodiments, other types of logging response equations may also exist, which will not be listed here. In the absence of full-spectrum elemental logging data, by combining multiple logging response equations simultaneously, and treating the inorganic framework mineral content and clay content of the target formation as unknown variables, the inorganic framework mineral content and clay content of the target formation can be quickly calculated for subsequent effective porosity calculations.

[0128] S206: Calculate the corresponding mixed inorganic mineral framework density based on the inorganic framework mineral component content information;

[0129] Specifically, in some embodiments, the density of the corresponding mixed inorganic mineral framework is calculated based on the content information of the inorganic framework mineral components, including:

[0130] Based on the inorganic framework mineral component content information, the corresponding mixed inorganic mineral framework density is calculated using the following formula:

[0131] ρ ma =∑(V mai ·ρ mai ), i = 1, 2, ..., n

[0132] Where, ρ ma For the density of the mixed inorganic mineral framework, V mai ρ represents the volume content of the i-th inorganic framework mineral component. mai Let be the density of the i-th inorganic framework mineral component, n be the total number of inorganic framework mineral components, and i be the ordinal number of the inorganic framework mineral component.

[0133] It can be understood that only by inorganic framework mineral component content information to characterize the inorganic framework of the target formation does not conform to the complex inorganic mineral distribution of the real formation, and therefore the mixed inorganic mineral framework density needs to be calculated to use the mixed inorganic mineral framework density for the effective porosity of the target formation, and improve the calculation accuracy of the effective porosity of the target formation.

[0134] S207: Calculate the effective porosity of the target formation by using the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content.

[0135] Specifically, in some embodiments, the effective porosity of the target formation is calculated by using the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content, including:

[0136] Obtain the density parameters corresponding to the formation density, total organic carbon content of kerogen and clay content; the density parameters include formation fluid density, kerogen density and wet clay density;

[0137] Based on the density parameters, the effective porosity of the target formation is calculated according to the following formula by using the formation volume density in the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content:

[0138]

[0139] Where, φ e is the effective porosity, ρ b is the formation volume density, ρ ma is the mixed inorganic mineral framework density, ρ f is the formation fluid density, V sh is the clay content, ρ sh is the wet clay density, TOC k is the total organic carbon content of kerogen, ρ k is the kerogen density.

[0140] It can be understood that ρ f is the formation fluid density, V sh is the clay content, ρ sh is the wet clay density, which is the formation parameter information, which can be obtained by table lookup, etc., the formation volume density is obtained according to the formation density, the clay content is also called the shale content, and the effective porosity of the target formation is calculated by comprehensively considering the organic framework and the mixed inorganic mineral framework, thereby improving the calculation accuracy of the effective porosity of the shale oil reservoir without nuclear magnetic resonance logging data.

[0141] In any of the above embodiments, first, the target well logging data is automatically acquired to obtain the formation density and total organic carbon content of the target formation, and then according to whether the element full spectrum logging data is included in the target well logging data, two cases are divided, the inorganic framework mineral component content information and clay content of the target formation are analyzed, since the element full spectrum logging data can more accurately analyze the inorganic framework mineral component content information and clay content, therefore, when the element full spectrum logging data is included in the target well logging data, the element full spectrum logging data is normalized analyzed, and when the element full spectrum logging data is not included in the target well logging data, the preset well logging data (usually the conventional well logging data) in the target well logging data is combined analyzed, to accurately determine the inorganic framework mineral component content information and clay content of the target formation, then the corresponding mixed inorganic mineral framework density is calculated according to the inorganic framework mineral component content information, to approach the mixed inorganic mineral framework density data in the real formation as much as possible, and the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content are comprehensively considered, in the case of no nuclear magnetic resonance logging data, based on the influence of organic and inorganic mineral framework in the real formation on porosity, the effective porosity of the shale oil reservoir is accurately and efficiently calculated.

[0142] Further, in some embodiments, taking the well logging data of a shale oil well in a certain research area and the experimental measurement data of the core of the well as an example, referring to the comparison diagram of well logging parameters and effective porosity shown in FIG. 8, in the case of no nuclear magnetic resonance logging data, based on the influence of organic and inorganic mineral framework in the real formation on porosity, the effective porosity of the shale oil reservoir is accurately and efficiently calculated. Figure 3 Figure 3 ​In the figure, the first track is the depth; in the second track, from left to right, GRKTH is the deuranium gamma curve, C1 is the caliper curve, and the curve GRTO is the natural gamma curve; the third track is the deep and shallow dual lateral resistivity curve, in which LLD represents the deep lateral resistivity curve, and LLS represents the shallow lateral resistivity curve; the fourth track is the three porosity logging curve, from left to right, including the neutron curve CNL, the density curve DEN, and the acoustic time difference curve AC; the fifth track is the inorganic skeleton mineral component content information and the clay content obtained based on the element full spectrum logging data processing, from left to right, including the clay content (Illite), the quartz content (Quartz), the calcite content (Calcite), the dolomite content (Dolomite), the halite content (Halite), the anhydrite content (Anhydrite), and the pyrite content (Pyrite); in the sixth track, from left to right, DWTOC_kerogen is the total organic carbon content of the kerogen, and DWTOC_Total is the total organic carbon content; in the seventh track, the curve PIGN_NK is the effective porosity without considering the influence of the organic kerogen, and the point-distributed PHIT_HE is the porosity measured by the core experiment; in the eighth track, PIGN_QE is the effective porosity calculated by using the method described in any one of the above embodiments, and the point-distributed PHIT_HE has the same meaning as the seventh track, that is, the porosity measured by the core experiment.

[0143] It can be seen from Figure 3 Compared with the curve PIGN_NK, the corrected PIGN_QE is closer to PHIT_HE, and the accuracy of PIGN_QE is higher, especially in the depth section with high kerogen content (2807-2810m, 2820-2824m), the effective porosity after kerogen correction is correspondingly reduced, which effectively improves the consistency with the core measurement value.

[0144] It should be noted that although the operations of the method of the present application are described in a specific order in the above embodiments and the accompanying drawings, this does not require or imply that the operations must be performed in this specific order, or that all the shown operations must be performed to achieve the desired results. Additionally or alternatively, certain steps can be omitted, a plurality of steps can be combined into one step, and / or one step can be divided into a plurality of steps.

[0145] Corresponding to the shale oil reservoir effective porosity determination method described above, some embodiments of the present specification also provide a shale oil reservoir effective porosity determination device, referring to Figure 4 As shown in the figure, in some embodiments, the device can include:

[0146] The receiving module 401 is configured to obtain target logging data;

[0147] The determining module 402 is configured to obtain formation density and total organic carbon content of the target formation by using target logging data.

[0148] The judging module 403 is configured to judge whether the target logging data comprises element full spectrum logging data.

[0149] The first analyzing module 404 is configured to, if the element full spectrum logging data is included, perform normalization analysis on the element full spectrum logging data to obtain inorganic framework mineral component content information and clay content of the target formation.

[0150] The second analyzing module 405 is configured to, if the element full spectrum logging data is not included, perform combination analysis on preset logging data in the target logging data to obtain inorganic framework mineral component content information and clay content of the target formation.

[0151] The mixed inorganic mineral framework density calculating module 406 is configured to calculate corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information.

[0152] The effective porosity calculating module 407 is configured to calculate effective porosity of the target formation by using the formation density, total organic carbon content of the dry kerogen, mixed inorganic mineral framework density and clay content.

[0153] For the convenience of description, the above apparatus is described in various units by function. Of course, the functions of the units can be implemented in one or more software and / or hardware in the implementation of the present specification.

[0154] It should be noted that in the embodiments of the present specification, the user information (including but not limited to user equipment information, user personal information, etc.) and data (including but not limited to data for analysis, stored data, displayed data, etc.) involved are all information and data authorized by the user and authorized by all parties.

[0155] It should be noted that the computer program product of the present specification is a software product for realizing the method of the present specification mainly through a computer program.

[0156] The embodiments of the present specification also provide a computer device. As shown in Figure 5As shown, in some embodiments of the specification, the computer device 502 can include one or more processors 504, such as one or more central processing units (CPUs) or graphics processing units (GPUs), each of which can implement one or more hardware threads. The computer device 502 can also include any memory 506 for storing any kind of information, such as code, settings, data, etc. In a particular embodiment, the memory 506 can store a computer program that is executable on the processor 504, which, when executed by the processor 504, can perform the instructions of the method of any of the embodiments described above.

[0157] Without limitation, for example, the memory 506 can include any one or combination of: any type of RAM, any type of ROM, a flash memory device, a hard disk, an optical disk, etc. More generally, any memory can use any technology for storing information. Further, any memory can provide volatile or nonvolatile retention of information. Further, any memory can represent a fixed or removable component of the computer device 502. In one case, the computer device 502 can perform any of the operations described above when the processor 504 executes associated instructions stored in any memory or combination of memories. The computer device 502 can also include one or more drive mechanisms 508, such as a hard drive mechanism, an optical disk drive mechanism, etc., for interacting with any memory.

[0158] The computer device 502 can also include an input / output interface 510 (I / O) for receiving various input (via input devices 512) and for providing various output (via output devices 514). One particular output mechanism can include a presentation device 516 and an associated graphical user interface 518 (GUI). In other embodiments, the input / output interface 510 (I / O), the input devices 512, and the output devices 514 can not be included, and the computer device 502 can be only one computer device in a network. The computer device 502 can also include one or more network interfaces 520 for exchanging data with other devices via one or more communication links 522. One or more communication buses 524 couple the above-described components together.

[0159] The communication links 522 can be implemented in any manner, such as through a local area network, a wide area network (e.g., the Internet), a point-to-point connection, etc., or any combination thereof. The communication links 522 can include any combination of hardwired links, wireless links, routers, gateway functionality, name servers, etc., governed by any protocol or combination of protocols.

[0160] The computer program instructions can also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer-implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart block or blocks. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof.

[0161] The computer program instructions can also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer-implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart block or blocks. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof.

[0162] The computer program instructions can also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer-implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart block or blocks. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof. Figure 1 one or more flowcharts and / or blocks in the flowcharts and / or a combination thereof.

[0163] In a typical configuration, a computer device includes one or more processors (CPUs), input / output interfaces, network interfaces, and memory.

[0164] The memory can include non-persistent memory, random access memory (RAM), and / or non-volatile memory, etc. in the form of a computer-readable medium, such as read only memory (ROM) or flash memory. The memory is an example of a computer-readable medium.

[0165] Computer-readable media includes permanent and non-permanent, movable and non-movable media, which can be implemented by any method or technology to store information. The information can be computer-readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, compact disc read-only memory (CD-ROM), digital versatile disc (DVD) or other optical storage, magnetic cassette, magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information accessible by a computer device. According to the definition in this specification, computer-readable media does not include transitory media such as modulated data signals and carriers.

[0166] Those skilled in the art will appreciate that embodiments of the present specification can be provided as methods, systems or computer program products. Therefore, embodiments of the present specification can take the form of entirely hardware embodiments, entirely software embodiments or embodiments combining software and hardware aspects. Moreover, embodiments of the present specification can take the form of a computer program product implemented on one or more computer-usable storage media (including, but not limited to, magnetic disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0167] Embodiments of the present specification can be described in the general context of computer-executable instructions, such as program modules, which are executed by computers. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. Embodiments of the present specification can also be practiced in distributed computing environments where tasks are performed by remote processing devices connected through a communication network. In a distributed computing environment, program modules can be located in both local and remote computer storage media including storage devices.

[0168] It should also be understood that in the embodiments of the present specification, the term "and / or" is only a description of the association relationship of the associated objects, which means that there can be three relationships. For example, A and / or B can mean that A exists alone, A and B exist together, and B exists alone. In addition, the character " / " in this paper generally means that the associated objects before and after are in an "or" relationship.

[0169] Each of the embodiments in the present specification is described in a progressive manner, and the same or similar parts between the embodiments can be referred to each other. Each of the embodiments focuses on the difference from other embodiments. In particular, for the system embodiments, since they are basically similar to the method embodiments, the description is relatively simple, and the relevant parts can be referred to the description of the method embodiments.

[0170] In the description of the present specification, the description of the terms "one embodiment", "some embodiments", "an example", "a specific example", or "some examples" means that the specific features, structures, materials or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the embodiments of the present specification. In the present specification, the illustrative description of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any suitable manner in any one or more embodiments or examples. In addition, the person skilled in the art can combine and combine the different embodiments or examples described in the present specification and the features of the different embodiments or examples without contradiction.

[0171] The above only describes the embodiments of the present application and is not intended to limit the present application. The present application can have various modifications and changes for those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included in the scope of claims of the present application.

Claims

1. A method of determining effective porosity of a shale oil reservoir, characterized by, The method comprises: obtaining target logging data; obtaining formation density and total organic carbon content of kerogen of the target formation by using the target logging data; determining whether the target logging data comprises element full spectrum logging data; if the element full spectrum logging data is included, performing normalization analysis on the element full spectrum logging data to obtain inorganic framework mineral component content information and clay content of the target formation; if the element full spectrum logging data is not included, performing combined analysis on preset logging data in the target logging data to obtain inorganic framework mineral component content information and clay content of the target formation; calculating corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information; calculating effective porosity of the target formation by using the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content.

2. The method of claim 1, wherein, obtaining formation density and total organic carbon content of kerogen of the target formation by using the target logging data comprises: calculating total organic carbon content of kerogen according to natural gamma-ray spectral logging data in the target logging data; obtaining formation density of the target formation by using the target logging data.

3. The method of claim 2, wherein, calculating total organic carbon content of kerogen according to natural gamma-ray spectral logging data in the target logging data comprises: calculating total organic carbon content of kerogen according to a uranium content curve in the natural gamma-ray spectral logging data by using the following formula: Among them, TOC k denoted as the total organic carbon content of kerogen, and U as the uranium content.

4. The method of claim 1, wherein, if the element full spectrum logging data is included, performing normalization analysis on the element full spectrum logging data to obtain inorganic framework mineral component content information and clay content of the target formation comprises: obtaining yields of different elements according to the element full spectrum logging data, and constructing a normalization analysis model based on oxide indices and detection sensitivity factors corresponding to different elements according to the yields of different elements; calculating contents of different elements according to the yields of different elements and the normalization analysis model; converting the contents of different elements by using an element-mineral conversion coefficient matrix to obtain inorganic framework mineral component content information and clay content.

5. The method of claim 1, wherein, The preset logging data at least comprises one or more of spontaneous potential logging data, natural gamma-ray logging data, acoustic logging data, neutron logging data, density logging data, lateral logging data, induction logging data and formation dip logging data.

6. The method of claim 5, wherein, if the element full spectrum logging data is not included, performing combined analysis on preset logging data in the target logging data to obtain inorganic framework mineral component content information and clay content of the target formation comprises: obtaining a plurality of logging response equations corresponding to the preset logging data; performing simultaneous combination based on the plurality of logging response equations to calculate inorganic framework mineral component content information and clay content of the target formation.

7. The method of claim 1, wherein, calculating corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information comprises: calculating corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information by using the following formula: p ma =∑(V mai ·ρ mai ),i=1,2,…,n wherein p ma is the bulk density of the mixed inorganic mineral framework, V mai is the volume content of the i-th inorganic framework mineral component, p mai is the density of the i-th inorganic framework mineral component, n is the total number of inorganic framework mineral components, and i is the ordinal number of the inorganic framework mineral component.

8. The method of claim 1, wherein, calculating effective porosity of the target formation by using the formation density, total organic carbon content of kerogen, mixed inorganic mineral framework density and clay content comprises: acquire the density parameters corresponding to the formation density, the total organic carbon content of the kerogen, and the clay content; the density parameters include a formation fluid density, a kerogen density, and a wet clay density; based on the density parameters, calculate the effective porosity of the target formation according to the following formula, using the bulk density in the formation density, the total organic carbon content of the kerogen, the mixed inorganic mineral framework density, and the clay content: where φ e is effective porosity, p b is formation bulk density, p ma is mixed inorganic mineral framework density, p f is formation fluid density, V sh is clay content, p sh is wet clay density, TOC k is total organic carbon content of dry kerogen, p k is dry kerogen density.

9. An apparatus for determining effective porosity of a shale oil reservoir, the apparatus comprising: The device comprises: a receiving module configured to acquire target logging data; a determining module configured to obtain the formation density and the total organic carbon content of the kerogen of the target formation using the target logging data; a judging module configured to judge whether the target logging data includes element full spectrum logging data; a first analysis module configured to, if the element full spectrum logging data is included, perform normalization analysis on the element full spectrum logging data to obtain inorganic framework mineral component content information and clay content of the target formation; a second analysis module configured to, if the element full spectrum logging data is not included, perform combined analysis on preset logging data in the target logging data to obtain inorganic framework mineral component content information and clay content of the target formation; a mixed inorganic mineral framework density calculation module configured to calculate the corresponding mixed inorganic mineral framework density according to the inorganic framework mineral component content information; an effective porosity calculation module configured to calculate the effective porosity of the target formation using the formation density, the total organic carbon content of the kerogen, the mixed inorganic mineral framework density, and the clay content.

10. A computer device comprising a memory, a processor, and a computer program stored on the memory, wherein, The computer program is run by the processor, and instructions of the method according to any one of claims 1-8 are executed.

11. A computer storage medium having stored thereon a computer program, characterized in that The computer program is run by the processor of the computer device, and instructions of the method according to any one of claims 1-8 are executed.

12. A computer program product, characterised in that, The computer program product comprises a computer program, and the computer program is run by the processor, and instructions of the method according to any one of claims 1-8 are executed.

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