Method and device for converting dynamic and static rock mechanics parameters for unconventional oil and gas blocks
By establishing a dynamic and static rock mechanics parameter conversion model using well logging data and downhole core tests, and performing anisotropic correction, the problem of obtaining static parameters in unconventional oil and gas blocks was solved, enabling accurate parameter conversion and fracturing design support.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Patents(China)
- Current Assignee / Owner
- CHINA UNIV OF PETROLEUM (BEIJING)
- Filing Date
- 2022-10-19
- Publication Date
- 2026-04-24
AI Technical Summary
In unconventional oil and gas blocks, it is difficult to effectively obtain static rock mechanics parameters of the main oil-producing layers, and dynamic rock mechanics parameters cannot accurately characterize the actual mechanical properties, thus failing to meet the requirements of fracturing construction design.
Dynamic rock mechanics parameters are determined by well logging data. Combined with mechanical experimental data from downhole core samples, a dynamic-to-static rock mechanics parameter conversion model is established. Anisotropy difference coefficients are considered for correction to achieve the conversion of dynamic parameters to static parameters.
It enables accurate conversion of static rock mechanics parameters of the main oil-producing layers in unconventional oil and gas blocks while taking anisotropy into account, supporting fracturing construction design.
Smart Images
Figure CN115600405B_ABST
Abstract
Description
Technical Field
[0001] This invention relates to the field of petroleum and natural gas engineering, and more specifically to a method and apparatus for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks. Background Technology
[0002] With the continuous development of conventional oil and gas resources, the development and utilization of unconventional oil and gas resources have gradually gained attention. Since conventional development methods cannot effectively develop unconventional oil and gas resources, it is necessary to use measures such as hydraulic fracturing to commercially develop unconventional oil and gas resources.
[0003] Obtaining accurate rock mechanics parameters (elastic modulus, Poisson's ratio, etc.) for the main oil-producing formations is crucial for fracturing design. However, due to the difficulty and high cost of coring these formations, complete and continuous static rock mechanics parameter profiles are often unavailable. With the continuous improvement of field logging interpretation techniques, relatively sophisticated logging technologies can be used to obtain logging data to calculate dynamic rock mechanics parameters of the reservoir and form continuous dynamic rock mechanics parameter profiles. However, since dynamic rock mechanics parameters cannot accurately characterize the actual mechanical properties of the main oil-producing formations, and the main oil-producing formations in unconventional blocks typically exhibit significant anisotropy, it is necessary to study the conversion relationship between dynamic and static rock mechanics parameters. This would allow dynamic rock mechanics parameters to be converted into static rock mechanics parameters, and the influence of the anisotropy of the main oil-producing formations on the converted values should be considered during the conversion process. Summary of the Invention
[0004] The purpose of this invention is to solve the problem of how to convert the dynamic and static rock mechanical parameters of the main oil-producing layers in unconventional blocks, taking into account the anisotropy of the main oil-producing layers. This invention provides a method and apparatus for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks.
[0005] To achieve the above objectives, the first aspect of this application provides a method for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks, comprising:
[0006] Based on the logging data of key wells in the target block, determine the dynamic rock mechanics parameters of the entire well section for each key well;
[0007] The depth of the main oil-producing layer in the target block is obtained so that multiple core sample sets can be collected from each key well according to the depth. The core sample set contains multiple standard cores obtained from different coring directions.
[0008] Based on the mechanical test data of standard rock cores, the static rock mechanical parameters in each core sampling direction of each core sample group are determined, so as to determine the average value of the static rock mechanical parameters of each core sample group.
[0009] Based on the dynamic rock mechanics parameters and their average values, determine the conversion model between dynamic and static rock mechanics parameters;
[0010] The dynamic rock mechanics parameters of each core sample group are converted according to the dynamic and static rock mechanics parameter conversion model to obtain the converted static rock mechanics parameters.
[0011] Based on the average value and static rock mechanics parameters, the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions was determined.
[0012] The static rock mechanics parameter conversion values are corrected based on the anisotropy difference coefficient to obtain the corresponding corrected static rock mechanics parameter values.
[0013] In one embodiment of this application, the anisotropy difference coefficient of the static rock mechanical parameters of each core sample group in different core sampling directions is determined based on the average value and static rock mechanical parameters, including:
[0014] The anisotropy difference coefficient is calculated using the following formula:
[0015]
[0016] Among them, X deg For static rock mechanics parameters, X ave γ is the average value. deg The anisotropy difference coefficient.
[0017] In one embodiment of this application, the static rock mechanics parameter conversion value is corrected according to the anisotropy difference coefficient to obtain the corresponding static rock mechanics parameter correction value, including:
[0018] The static rock mechanics parameter conversion values are corrected using the following formula:
[0019] X degc =(1+γ) deg )×X pre (2)
[0020] Among them, X degc X is the static rock mechanics parameter correction value. pre For static rock mechanics parameter conversion values, γ deg The anisotropy difference coefficient.
[0021] In one embodiment of this application, the depth of the main oil-producing layer in the target block is obtained to collect multiple core sample sets from each key well, including:
[0022] Obtain the top and bottom depths of the main oil-producing layers;
[0023] Multiple coring depths are determined for each key well between the top and bottom depths to obtain core sample sets at each coring depth, wherein there is a preset interval between each coring depth.
[0024] In one embodiment of this application, a dynamic-static rock mechanics parameter conversion model is determined based on the average values of dynamic and static rock mechanics parameters, including:
[0025] By performing regression fitting between dynamic rock mechanics parameters and the corresponding average static rock mechanics parameters, several different functional relationships are obtained.
[0026] Among the functional relationships, the one with the correlation coefficient closest to 1 is selected as the conversion model for dynamic and static rock mechanics parameters.
[0027] In one embodiment of this application, the method further includes:
[0028] Based on the well location distribution, drilled formations, production status, and proven reserves of the target block, several key wells in the target block are identified.
[0029] In one embodiment of this application, the logging data includes P-wave transit time, S-wave transit time, reservoir rock density, and clay content data.
[0030] The second aspect of this application provides a device for converting dynamic and static rock mechanics parameters in unconventional oil and gas blocks, the device comprising:
[0031] The dynamic rock mechanics parameter acquisition module is used to determine the dynamic rock mechanics parameters of each key well section based on the logging data of key wells in the target block.
[0032] The reservoir depth acquisition module is used to obtain the depth of the main oil-producing layer in the target block, so as to collect multiple core sample sets for each key well according to the depth. The core sample set contains multiple standard cores obtained from different coring directions.
[0033] The static rock mechanics parameter acquisition module is used to determine the static rock mechanics parameters in each core sampling direction of each core sample group based on the mechanical experimental data of the standard core, so as to determine the average value of the static rock mechanics parameters of each core sample group.
[0034] The model acquisition module is used to determine the dynamic-static rock mechanics parameter conversion model based on the dynamic rock mechanics parameters and their average values.
[0035] The parameter conversion module is used to convert the dynamic rock mechanics parameters of each core sample group according to the dynamic and static rock mechanics parameter conversion model to obtain the converted static rock mechanics parameters.
[0036] An anisotropy correction module is used to determine the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions based on the average value and static rock mechanics parameters.
[0037] The static rock mechanics parameter conversion values are corrected based on the anisotropy difference coefficient to obtain the corresponding corrected static rock mechanics parameter values.
[0038] A third aspect of this application provides an electronic device including a processor and a memory, the memory storing machine-executable instructions executable by the processor, the processor executing the machine-executable instructions to implement the above-described method for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks.
[0039] A fourth aspect of this application provides a computer-readable storage medium, characterized in that the machine-readable storage medium stores instructions that, when executed by a processor, cause the processor to implement the above-described method for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks.
[0040] Through the above technical solution, the static rock mechanics parameters of the main oil-producing layers in unconventional oil and gas blocks can be obtained by converting the dynamic rock mechanics parameters calculated from well logging data. At the same time, given the obvious anisotropic nature of the main oil-producing layers in most unconventional oil and gas blocks, anisotropic difference coefficients corresponding to different core directions are introduced to correct the conversion results, so that the corrected conversion results can characterize the static rock mechanics parameters of the main oil-producing layers in different directions.
[0041] Other features and advantages of the embodiments of the present invention will be described in detail in the following detailed description section. Attached Figure Description
[0042] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:
[0043] Figure 1 The illustration shows a schematic diagram of the process for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks according to an embodiment of this application;
[0044] Figure 2 The diagram illustrates a downhole core sampling method according to an embodiment of this application. Detailed Implementation
[0045] The specific embodiments of this application will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit this application.
[0046] It should be noted that if the embodiments of this application involve directional indicators (such as up, down, left, right, front, back, etc.), the directional indicators are only used to explain the relative positional relationship and movement of the components in a certain specific posture (as shown in the figure). If the specific posture changes, the directional indicators will also change accordingly.
[0047] Furthermore, if the embodiments of this application involve descriptions such as "first" or "second," these descriptions are for descriptive purposes only and should not be construed as indicating or implying their relative importance or implicitly specifying the number of technical features indicated. Therefore, features defined with "first" or "second" may explicitly or implicitly include at least one of those features. Additionally, the technical solutions of various embodiments can be combined with each other, but this must be based on the ability of those skilled in the art to implement them. If the combination of technical solutions is contradictory or impossible to implement, it should be considered that such a combination of technical solutions does not exist and is not within the scope of protection claimed in this application.
[0048] The mechanical parameters of rocks are fundamental to oil and gas engineering design. Currently, there are two commonly used methods for determining rock mechanical parameters: static methods and dynamic methods. Static rock mechanical parameters can be obtained by statically loading and measuring the deformation of a rock sample; dynamic rock mechanical parameters can be obtained by measuring the propagation time of ultrasound in a rock sample and combining this with the measured composition and density properties of the rock sample.
[0049] Static rock mechanics parameters are more representative of the loading conditions of rocks in oil and gas engineering than dynamic rock mechanics parameters. However, determining static rock mechanics parameters requires extracting core samples from the studied strata underground and conducting loading tests in the laboratory, which is time-consuming and costly. Dynamic rock mechanics parameters, on the other hand, can be obtained by converting well logging data directly obtained in the field. If a conversion model between dynamic and static rock mechanics parameters can be determined, static rock mechanics parameters can be obtained directly using acoustic tools such as sonic logging.
[0050] This application provides a method for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks. Figure 1 This illustration schematically depicts a process flow diagram for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks according to an embodiment of this application. Figure 1 As shown in the embodiments of this application, a method for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks is provided, including:
[0051] Step S101: Based on the logging data of key wells in the target block, determine the dynamic rock mechanics parameters of the entire well section of each key well.
[0052] After acquiring logging data from key wells in the target block, the electronic equipment used for calculation can determine the dynamic rock mechanics parameters of the entire well section of each key well based on the obtained logging data. The dynamic rock mechanics parameters of the entire well section at each continuous depth downhole are thus obtained as a continuous dynamic rock mechanics parameter profile of each key well.
[0053] In one embodiment of this application, the logging data includes on-site P-wave transit time, S-wave transit time, reservoir rock density, and clay content data. The electronic equipment uses the above logging data to calculate dynamic rock mechanical parameters.
[0054] In one embodiment of this application, the dynamic rock mechanics parameters include dynamic elastic modulus, dynamic Poisson's ratio, dynamic compressive strength, and dynamic tensile strength, which can be calculated using their respective formulas.
[0055] Dynamic elastic modulus:
[0056]
[0057] Among them, E d ρ is the dynamic elastic modulus, in GPa; ρ is the reservoir rock density, in g / cm³. 3 (grams per cubic centimeter); Δt s Transverse wave time difference, unit: μs / ft (microseconds per foot); Δt p P-wave time difference, unit: μs / ft (microseconds per foot).
[0058] Dynamic Poisson's ratio:
[0059]
[0060] Where, μ d The dynamic Poisson's ratio; Δt s Transverse wave time difference, unit: μs / ft (microseconds per foot); Δt p P-wave time difference, unit: μs / ft (microseconds per foot).
[0061] Dynamic compressive strength:
[0062] σ d =E d [0.008V sh +0.0045(1-V sh (5)
[0063] Where, σ dDynamic compressive strength, unit: MPa; V sh Δt represents the percentage of reservoir clay content. s Transverse wave time difference, unit: μs / ft (microseconds per foot); Δt p P-wave time difference, unit: μs / ft (microseconds per foot).
[0064] Dynamic tensile strength:
[0065]
[0066] Among them, T d Dynamic tensile strength, unit: MPa; ρ is reservoir rock density, unit: g / cm³. 3 (grams per cubic centimeter); Δt s Transverse wave time difference, unit: μs / ft (microseconds per foot); Δt p P-wave time difference, unit: μs / ft (microseconds per foot).
[0067] In one embodiment of this application, considering the high cost and other disadvantages of measuring shear wave transit time in oilfields, well logging data does not include shear wave transit time. The electronic device can convert the acquired P-wave transit time into shear wave transit time using the following formula:
[0068]
[0069] Where, Δt s ρ is the transverse wave transit time, in μs / ft (microseconds per foot); ρ is the reservoir rock density, in g / cm³. 3 (grams per cubic centimeter); Δt p For P-wave time difference, μs / ft; e is the natural logarithm.
[0070] Step S102: Obtain the depth of the main oil-producing layer in the target block to collect multiple core sample sets from each key well.
[0071] Within the entire target block, the combination of oil-bearing layers that are relatively stable in distribution, have good physical properties, possess certain interlayer conditions, and have a certain reserve, and can be independently exploited, is called the main oil-producing layer. The core sampling depth of each key well's core sample set needs to be determined based on the depth of the main oil-bearing layer in the target block, so that the experimental data of the standard cores used for mechanical testing in the core sample set can accurately characterize the rock loading conditions of the main oil-bearing layer in the target block.
[0072] In one embodiment of this application, step S102 includes:
[0073] Obtain the top and bottom depths of the main oil-producing layers;
[0074] Multiple coring depths are determined for each key well between the top and bottom depths to obtain core sample sets at each coring depth, wherein there is a preset interval between each coring depth.
[0075] After obtaining the top and bottom depths of the main oil-producing layer, the electronic equipment determines multiple coring depths for each key well between the top and bottom depths. These coring depths are spaced at intervals. In one embodiment of this application, the interval is set to 2 meters. The specific value of the interval can be determined based on the difference between the top and bottom depths of the main oil-producing layer, and it is necessary to ensure a sufficient number of coring depths (i.e., the number of standard cores) so that subsequent experimental data can cover the rock loading conditions at the full depth of the main oil-producing layer as much as possible, and the conversion accuracy of the dynamic and static rock mechanics parameter conversion model can also be higher. Therefore, this application does not impose any limitations on the specific value of the above-mentioned interval.
[0076] After the electronic equipment determined multiple coring depths for each key well, a core sample set was collected on-site from each coring depth. In order to perform anisotropic correction on the static rock mechanics parameter conversion values obtained by the dynamic-static rock mechanics conversion model, each core sample set contained multiple standard cores obtained from different coring directions. Figure 2 This illustration schematically shows a downhole core sampling method according to an embodiment of this application, such as... Figure 2 As shown, in one embodiment of this application, the coring direction includes a 0° direction (i.e., parallel to the wellbore axis of the key well) and a 90° direction (perpendicular to the wellbore axis of the key well). One to two standard core samples are taken from each coring direction for subsequent mechanical experiments. It is worth noting that the coring direction is not limited to the two directions provided in this embodiment; the coring direction can be other directions (such as a direction at 45° to the wellbore axis of the key well). The coring direction can be determined according to the required anisotropy correction needs, and this application does not limit this.
[0077] Step S103: Based on the mechanical experimental data of the standard core, determine the static rock mechanical parameters in each core sampling direction of each core sample group, so as to determine the average value of the static rock mechanical parameters of each core sample group.
[0078] In one embodiment of this application, static rock mechanics parameters include static elastic modulus, static Poisson's ratio, static compressive strength, and static tensile strength, which correspond to the types of dynamic rock mechanics parameters.
[0079] In one embodiment of this application, the mechanical tests include a triaxial compression test (the experimental data from the triaxial compression test is used to obtain the static elastic modulus, static Poisson's ratio, and static compressive strength of the reservoir core) and a Brazilian test (the experimental data from the Brazilian test is used to obtain the static tensile strength). The dimensions of the obtained standard cores correspond to the standard samples of the above two mechanical tests: the standard cores are all cylindrical, with the standard cores used for the triaxial compression test having a diameter of approximately 25 mm and a length of approximately 50 mm, and the standard cores used for the Brazilian test having a diameter of approximately 50 mm and a length of approximately 25 mm. Figure 2 As shown, the standard cores used for mechanical experiments in a core sample group are all collected from a single full-diameter core. The length of the full-diameter core should be no less than 10 cm. During on-site core sampling, the center position of the full-diameter core is controlled at the target core sampling depth. The mechanical experimental data of the standard cores collected from the full-diameter cores directly correspond to the core sampling depth of that full-diameter core.
[0080] After the electronic device acquires the mechanical experimental data of the standard core of each core sample group, it determines the static rock mechanical parameters of each core sample group in each core sampling direction based on the experimental data. After determining the static rock mechanical parameters in each core sampling direction (including the four static rock mechanical parameters mentioned in the above embodiments), their average values can be determined (that is, each static rock mechanical parameter of each core sample group corresponds to an average value).
[0081] Step S104: Determine the dynamic and static rock mechanics parameter conversion model based on the dynamic rock mechanics parameters and the average value.
[0082] The dynamic rock mechanics parameters of all core sample groups obtained from logging data of each key well, and the average value of the static rock mechanics parameters of all core sample groups obtained from mechanical experimental data, can characterize the loading conditions of the main oil-producing layers in the entire target block. Therefore, to obtain a dynamic and static rock mechanics parameter conversion model applicable to the entire target block, it is necessary to determine the dynamic rock mechanics parameters of all core sample groups and the average value of the static rock mechanics parameters of all core sample groups obtained from mechanical experimental data.
[0083] In one embodiment of this application, step S104 includes:
[0084] By performing regression fitting between the dynamic rock mechanics parameters and the average value, several different functional relationships are obtained;
[0085] Among the functional relationships, the one with the correlation coefficient closest to 1 is selected as the conversion model for dynamic and static rock mechanics parameters.
[0086] The electronic equipment performs various regression fitting methods on the dynamic rock mechanics parameters of all key wells across the entire well section and the average static rock mechanics parameters of all core sample groups. These methods (i.e., the regression fitting and the establishment of the dynamic-to-static rock mechanics parameter conversion model are based on the dynamic rock mechanics parameters of all key wells and the average static rock mechanics parameters of all core sample groups) include linear fitting, exponential fitting, logarithmic fitting, and power-law fitting. Each fitting method yields a functional relationship that characterizes the conversion relationship between the dynamic rock mechanics parameters and the average static rock mechanics parameters.
[0087] After obtaining multiple functional relationships, the correlation coefficient of each functional relationship is calculated to characterize the conversion accuracy of each functional relationship. The correlation coefficients of each functional relationship are compared, and the functional relationship with the correlation coefficient closest to 1 is selected as the conversion model for dynamic and static rock mechanics parameters.
[0088] In one embodiment of this application, if multiple functional relationships with the same correlation coefficient exist, meaning that the conversion accuracy of these multiple functional relationships is the same, then the functional relationship with the lowest formula complexity among those with the same accuracy is selected as the dynamic-static rock mechanics parameter conversion model. For example, the formula complexity of a linear functional relationship is less than that of a quadratic polynomial functional relationship. If their correlation coefficients are the same, the linear functional relationship is selected as the dynamic-static rock mechanics parameter conversion model.
[0089] Those skilled in the art will understand that the "dynamic rock mechanics parameters" and the "average value of static rock mechanics parameters" in the above-mentioned "fitting the dynamic rock mechanics parameters of all key well sections with the average value of static rock mechanics parameters of all core sample groups in various ways" are the same type of parameter (e.g. fitting the obtained dynamic elastic modulus with the average value of static elastic modulus). The average value of dynamic rock mechanics parameters and static rock mechanics parameters of different parameter types cannot be fitted. Each parameter type corresponds to a dynamic-static rock mechanics parameter conversion model.
[0090] Step S105: Convert the dynamic rock mechanics parameters of each core sample group according to the dynamic and static rock mechanics parameter conversion model to obtain the static rock mechanics parameter conversion values.
[0091] After determining the dynamic and static rock mechanics parameter conversion model, the electronic equipment converts the dynamic rock mechanics parameters of each core sample group (the dynamic rock mechanics parameters obtained by the electronic equipment are the dynamic rock mechanics parameters of the entire well section. Each core sample group has its corresponding core sampling depth, so the dynamic rock mechanics parameters corresponding to each core sample group can be directly matched) to obtain the conversion value of the corresponding static rock mechanics parameters.
[0092] Step S106: Based on the average value and the static rock mechanics parameters, determine the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions.
[0093] Since the main oil-producing layers in unconventional blocks usually have significant anisotropy, it is necessary to perform anisotropy correction on the obtained static rock mechanics parameters. Anisotropy correction first requires determining the anisotropy difference coefficient in different core sampling directions for each core sample group.
[0094] In one embodiment of this application, the anisotropy difference coefficient can be calculated using the following formula:
[0095]
[0096] Among them, X deg Let X be the static rock mechanics parameter along a certain coring direction. ave γ represents the average static rock mechanical parameters of this core sample group. deg This is the anisotropy difference coefficient in the centering direction.
[0097] Step S107: Correct the static rock mechanics parameter conversion values based on the anisotropy difference coefficient to obtain the corresponding corrected static rock mechanics parameter values.
[0098] After determining the anisotropy difference coefficients of each core sample group in different core sampling directions, the electronic equipment corrects the static rock mechanics parameter conversion values of each core sample group in different core sampling directions.
[0099] In one embodiment of this application, the converted values of static rock mechanics parameters are corrected using the following formula:
[0100] X degc =(1+γ) deg )×X pre (2)
[0101] Among them, X degc The static rock mechanics parameter correction values for each core sample group under different core sampling directions, X pre Transformed values of static rock mechanics parameters, γ, for each core sample group under different core sampling directions. deg It is the anisotropy difference coefficient for different core sampling directions for each core sample group.
[0102] In this way, the corrected conversion results can characterize the static rock mechanical parameters of the main oil-producing layers in different directions.
[0103] In one embodiment of this application, the above-mentioned static rock mechanical parameter correction values can be compared with the static mechanical parameters obtained through mechanical experiments to verify the error between the correction results and the experimental values.
[0104] In one embodiment of this application, the method further includes the following step before step S101:
[0105] Based on the well location distribution, drilled formations, production status, and proven reserves of the target block, several key wells in the target block are identified.
[0106] When determining key wells, in addition to the four factors mentioned above, electronic equipment must also ensure that key wells are evenly distributed in the target block and that there are no fewer than 15 key wells, so that the selected key wells can characterize the strata characteristics of the entire target block.
[0107] Through the technical solutions in the above embodiments, the static rock mechanics parameters of the main oil-producing layers in unconventional oil and gas blocks can be obtained by converting the dynamic rock mechanics parameters calculated from well logging data. At the same time, given that the main oil-producing layers in most unconventional oil and gas blocks have obvious anisotropic properties, anisotropic difference coefficients corresponding to different core directions are introduced to correct the conversion results, so that the corrected conversion results can characterize the static rock mechanics parameters of the main oil-producing layers in different directions.
[0108] The following section uses the Lucaogou Formation reservoir in the Jimsar block as an example to illustrate the specific application of the dynamic and static rock mechanics parameter conversion method for unconventional oil and gas blocks described in the above embodiments:
[0109] Key wells were selected for the Jimsar block. In this embodiment, wells J301, J302, J303, J174, J176, J187, J10020, J10038, J10044, and J10057 were selected as key research wells.
[0110] Determine the dynamic rock mechanics parameters (dynamic elastic modulus, dynamic Poisson's ratio, dynamic compressive strength, and dynamic tensile strength) of the main oil-producing layers of the aforementioned key wells;
[0111] Mechanical experimental data were obtained from downhole cores of the main oil-producing layers of the key wells mentioned above (a total of 114 standard cores of various types were obtained in this example, including multiple different core sampling directions). Static rock mechanical parameters (static elastic modulus, static Poisson's ratio, static compressive strength, and static tensile strength) of each core sample group in different core sampling directions were determined, and the average value of the static rock mechanical parameters was calculated.
[0112] The average values of static rock mechanics parameters were fitted to the dynamic rock mechanics parameters, and a preferred functional relationship was selected as the transformation model for dynamic and static rock mechanics parameters. A linear functional relationship was used for the dynamic-to-static transformation of elastic modulus, a quadratic polynomial functional relationship for Poisson's ratio, a power-law functional relationship for compressive strength, and a linear functional relationship for tensile strength.
[0113] Anisotropic correction was performed on the obtained static rock mechanics parameter conversion values, and the error between the corrected conversion results and the experimental test values was less than 10%.
[0114] In one embodiment of this application, a device for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks is provided. The device includes:
[0115] The dynamic rock mechanics parameter acquisition module is used to determine the dynamic rock mechanics parameters of each key well section based on the logging data of key wells in the target block.
[0116] The reservoir depth acquisition module is used to obtain the depth of the main oil-producing layer in the target block, so as to collect multiple core sample sets for each key well. The core sample set contains multiple standard cores obtained from different coring directions.
[0117] The static rock mechanics parameter acquisition module is used to determine the static rock mechanics parameters in each core sampling direction of each core sample group based on the mechanical experimental data of the standard core, so as to determine the average value of the static rock mechanics parameters of each core sample group.
[0118] The model acquisition module is used to determine the dynamic-static rock mechanics parameter conversion model based on the dynamic rock mechanics parameters and their average values.
[0119] The parameter conversion module is used to convert the dynamic rock mechanics parameters of each core sample group according to the dynamic and static rock mechanics parameter conversion model to obtain the converted static rock mechanics parameters.
[0120] An anisotropy correction module is used to determine the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions based on the average value and static rock mechanics parameters.
[0121] The static rock mechanics parameter conversion values are corrected based on the anisotropy difference coefficient to obtain the corresponding corrected static rock mechanics parameter values.
[0122] In one embodiment of this application, an electronic device is provided, including a processor and a memory. The memory stores machine-executable instructions that can be executed by the processor. The processor can execute the machine-executable instructions to implement the dynamic and static rock mechanical parameter conversion method for unconventional oil and gas blocks described in the above embodiment.
[0123] In one embodiment of this application, a computer-readable storage medium is provided, on which instructions are stored, which, when executed by a processor, cause the processor to implement the dynamic and static rock mechanical parameter conversion method for unconventional oil and gas blocks described in the above embodiment.
[0124] In one embodiment of this application, a computer program product is also provided, including a computer program that, when executed by a processor, implements the dynamic and static rock mechanics parameter conversion method for unconventional oil and gas blocks according to the above embodiments.
[0125] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.
[0126] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 The computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The functions specified in one or more boxes. These computer program instructions may 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, thereby providing instructions that execute on the computer or other programmable apparatus for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.
[0127] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.
[0128] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.
[0129] Computer-readable media includes both permanent and non-permanent, removable and non-removable media that can store information by any method or technology. Information can be computer-readable instructions, data structures, modules of programs, 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, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.
[0130] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.
[0131] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.
Claims
1. A method for converting dynamic and static rock mechanical parameters in unconventional oil and gas blocks, characterized in that, The method includes: Based on the logging data of key wells in the target block, determine the dynamic rock mechanics parameters of each key well section. The depth of the main oil-producing layer in the target block is obtained, and multiple core sample sets are collected for each key well according to the depth, wherein the core sample set includes multiple standard cores obtained from different coring directions. Based on the mechanical experimental data of the standard rock core, determine the static rock mechanical parameters in each core sampling direction of each core sample group, so as to determine the average value of the static rock mechanical parameters of each core sample group; Based on the dynamic rock mechanics parameters and the average value, a conversion model for dynamic and static rock mechanics parameters is determined; The dynamic rock mechanics parameters of each core sample group are converted according to the dynamic and static rock mechanics parameter conversion model to obtain the static rock mechanics parameter conversion values; Based on the average value and the static rock mechanics parameters, the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions is determined; The static rock mechanics parameter conversion value is corrected according to the anisotropy difference coefficient to obtain the corresponding static rock mechanics parameter correction value. Specifically, based on the average value and the static rock mechanics parameters, the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions is determined, including: The anisotropy difference coefficient is calculated using the following formula: （1） in, These are the static rock mechanics parameters. The average value is... The anisotropy difference coefficient is mentioned above; The step of correcting the converted static rock mechanics parameter values based on the anisotropy difference coefficient to obtain corresponding corrected static rock mechanics parameter values includes: The converted values of the static rock mechanics parameters are corrected using the following formula: （2） in, These are the static rock mechanics parameter correction values. These are the converted values of the static rock mechanics parameters. The anisotropy difference coefficient is the coefficient of variation.
2. The method for converting dynamic and static rock mechanical parameters according to claim 1, characterized in that, The process of obtaining the depth of the main oil-producing layers in the target block, and collecting multiple core sample sets from each of the key wells, includes: Obtain the top and bottom depths of the main oil-producing layers; Multiple coring depths are determined for each key well between the top depth and the bottom depth to obtain the core sample set at each coring depth, wherein a preset interval exists between each coring depth.
3. The method for converting dynamic and static rock mechanical parameters according to claim 1, characterized in that, The step of determining the dynamic-static rock mechanics parameter conversion model based on the dynamic rock mechanics parameters and the average value includes: By performing regression fitting between the dynamic rock mechanics parameters and the average value, several different functional relationships are obtained; Among the functional relationships, the one with the correlation coefficient closest to 1 is selected as the dynamic and static rock mechanics parameter conversion model.
4. The method for converting dynamic and static rock mechanical parameters according to claim 1, characterized in that, The method further includes: Based on the well location distribution, drilled formations, production status, and proven reserves of the target block, a number of key wells in the target block are determined.
5. The method for converting dynamic and static rock mechanical parameters according to claim 1, characterized in that, The logging data includes P-wave transit time, S-wave transit time, reservoir rock density, and clay content data.
6. A device for converting dynamic and static rock mechanics parameters in unconventional oil and gas blocks, characterized in that, The device includes: The dynamic rock mechanics parameter acquisition module is used to determine the dynamic rock mechanics parameters of each key well section based on the logging data of key wells in the target block. The reservoir depth acquisition module is used to acquire the depth of the main oil-producing layer in the target block, so as to collect multiple core sample sets for each key well according to the depth, wherein the core sample set includes multiple standard cores obtained from different coring directions. The static rock mechanics parameter acquisition module is used to determine the static rock mechanics parameters in each core sampling direction of each core sample group based on the mechanical experimental data of the standard core, so as to determine the average value of the static rock mechanics parameters of each core sample group. The model acquisition module is used to determine the dynamic-static rock mechanics parameter conversion model based on the dynamic rock mechanics parameters and the average value. The parameter conversion module is used to convert the dynamic rock mechanics parameters of each core sample group according to the dynamic and static rock mechanics parameter conversion model to obtain the static rock mechanics parameter conversion values. An anisotropy correction module is used to determine the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions based on the average value and the static rock mechanics parameters. The static rock mechanics parameter conversion value is corrected according to the anisotropy difference coefficient to obtain the corresponding static rock mechanics parameter correction value. Specifically, based on the average value and the static rock mechanics parameters, the anisotropy difference coefficient of the static rock mechanics parameters of each core sample group in different core sampling directions is determined, including: The anisotropy difference coefficient is calculated using the following formula: （1） in, These are the static rock mechanics parameters. The average value is... The anisotropy difference coefficient is mentioned above; The step of correcting the converted static rock mechanics parameter values based on the anisotropy difference coefficient to obtain corresponding corrected static rock mechanics parameter values includes: The converted values of the static rock mechanics parameters are corrected using the following formula: （2） in, These are the static rock mechanics parameter correction values. These are the converted values of the static rock mechanics parameters. The anisotropy difference coefficient is the coefficient of variation.
7. An electronic device, characterized in that, It includes a processor and a memory, the memory storing machine-executable instructions that can be executed by the processor, the processor executing the machine-executable instructions to implement the dynamic and static rock mechanical parameter conversion method for unconventional oil and gas blocks as described in any one of claims 1 to 5.
8. A computer-readable storage medium, characterized in that, The readable storage medium stores instructions that, when executed by a processor, cause the processor to implement the method for converting dynamic and static rock mechanical parameters for unconventional oil and gas blocks according to any one of claims 1 to 5.