A method, apparatus, equipment and storage medium for spatial distribution visualization of oil and gas reservoirs

Abstract

This invention discloses a method, apparatus, equipment, and storage medium for displaying the spatial distribution of oil and gas reservoirs. The method includes: spatially locating, quantifying, and processing carbonate reservoirs to determine their spatial distribution information; detecting and predicting the spatial distribution of fluids within the reservoir to determine their spatial distribution information; determining the spatial distribution of fractures and vulnerabilities in the carbonate rocks based on the reservoir's spatial distribution information and the spatial distribution of fractures; and rendering and displaying the spatial distribution information of the carbonate oil and gas reservoir based on the fracture and vulnerabilities and the fluid spatial distribution information. Through the technical solutions of this invention, the spatial distribution of carbonate oil and gas reservoirs can be visualized and made transparent, making drilling targets clearer and more precise.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration technology, and in particular to a method, apparatus, equipment and storage medium for displaying the spatial distribution of oil and gas reservoirs. Background Technology

[0002] As oil and gas exploration moves towards ultra-deep formations, depths below 7000 meters have become a key focus. Ultra-deep drilling is challenging and costly, and accurately selecting high-yield well locations is a core problem. Currently, seismic characterization of deep or ultra-deep carbonate reservoirs remains difficult, and the timing, location, and quantitative characterization of hydrocarbon accumulation processes also hinders accurate reservoir identification. Therefore, there is an urgent need for a method to visualize the spatial distribution of oil and gas reservoirs, making drilling targets clearer and more precise. Summary of the Invention

[0003] This invention provides a method, apparatus, equipment, and storage medium for displaying the spatial distribution of oil and gas reservoirs, so as to realize the visualization and transparency of the spatial distribution of carbonate oil and gas reservoirs, making the drilling targets clearer and more distinct.

[0004] In a first aspect, embodiments of the present invention provide a method for displaying the spatial distribution of oil and gas reservoirs, including:

[0005] Spatial location, volume determination, and quantitative analysis of carbonate reservoirs were performed to determine their spatial distribution information.

[0006] The fluid in the reservoir is detected and its spatial distribution is predicted to determine the spatial distribution information of the fluid in the reservoir;

[0007] Based on the spatial distribution information of reservoirs and the spatial distribution information of carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined.

[0008] Based on the spatial distribution information of fractures and cavities and the aforementioned spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed.

[0009] Secondly, embodiments of the present invention also provide an oil and gas reservoir spatial distribution display device, comprising:

[0010] The module for determining the spatial distribution of carbonate reservoirs is used to perform spatial positioning, volume determination, and quantitative processing of carbonate reservoirs to determine their spatial distribution information.

[0011] The fluid spatial distribution determination module is used to detect and predict the spatial distribution of fluid in the reservoir, and determine the fluid spatial distribution information in the reservoir.

[0012] The fracture-cavity spatial distribution determination module is used to determine the spatial distribution information of fractures and cavities in carbonate rocks based on the spatial distribution information of reservoirs and the spatial distribution information of fractures in carbonate rocks.

[0013] The spatial distribution display module renders and displays the spatial distribution information of carbonate oil and gas reservoirs based on the spatial distribution information of fractures and cavities and the aforementioned fluid spatial distribution information.

[0014] Thirdly, embodiments of the present invention also provide an electronic device, characterized in that the electronic device comprises: at least one processor; and

[0015] A memory communicatively connected to the at least one processor; wherein,

[0016] The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to execute the oil and gas reservoir spatial distribution visualization method provided in any embodiment of the present invention.

[0017] Fourthly, embodiments of the present invention also provide a computer-readable storage medium, characterized in that the computer-readable storage medium stores computer instructions, which are used to enable a processor to execute the oil and gas reservoir spatial distribution display method provided in any embodiment of the present invention.

[0018] The technical solution of this invention, through spatial positioning, volume determination, and quantitative processing of carbonate reservoirs, determines the spatial distribution information of carbonate reservoirs, thereby obtaining reservoir volumes close to actual values ​​and achieving quantitative reservoir characterization; it performs property detection and spatial distribution prediction of fluids in the reservoir, thereby obtaining accurate fluid property detection results and fluid spatial distribution information; based on the spatial distribution information of the reservoir and the spatial distribution information of carbonate fractures, it determines the spatial distribution information of carbonate fractures and vulnerabilities; based on the spatial distribution information of fractures and vulnerabilities and the aforementioned fluid spatial distribution information, it renders and displays the spatial distribution information of carbonate oil and gas reservoirs, thereby obtaining a three-dimensional visualized oil and gas reservoir spatial distribution, achieving three-dimensional transparent and quantitative characterization of deep carbonate oil and gas reservoirs, and further realizing reservoir sculpting on the basis of carbonate reservoir sculpting, making the drilling target clearer and more distinct.

[0019] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0020] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0021] Figure 1 This is a flowchart of a method for displaying the spatial distribution of oil and gas reservoirs according to Embodiment 1 of the present invention;

[0022] Figure 2 This is a three-dimensional visualization of the spatial distribution of carbonate reservoirs according to Embodiment 1 of the present invention;

[0023] Figure 3 This is a three-dimensional visualization of the spatial distribution of carbonate reservoirs and oil and gas reservoirs according to Embodiment 1 of the present invention;

[0024] Figure 4 This is a flowchart of a method for displaying the spatial distribution of oil and gas reservoirs according to Embodiment 2 of the present invention;

[0025] Figure 5 This is a schematic diagram of the structure of an oil and gas reservoir spatial distribution display device provided in Embodiment 3 of the present invention;

[0026] Figure 6 This is a schematic diagram of the structure of an electronic device for implementing the method for displaying the spatial distribution of oil and gas reservoirs according to an embodiment of the present invention. Detailed Implementation

[0027] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0028] It should be noted that the terms "target," "current," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0029] Example 1

[0030] Figure 1 This is a flowchart illustrating a method for displaying the spatial distribution of oil and gas reservoirs, as provided in Embodiment 1 of the present invention. This embodiment is applicable to displaying the spatial distribution of deep or ultra-deep carbonate oil and gas reservoirs. Figure 1 As shown, this method can be executed by an oil and gas reservoir spatial distribution display device, which can be implemented in hardware and / or software and can be configured in electronic equipment. For example... Figure 1 As shown, the method specifically includes the following steps:

[0031] S110. Spatial location, volume determination, and quantitative processing of carbonate reservoirs are performed to determine the spatial distribution information of carbonate reservoirs.

[0032] Carbonate rocks can refer to any rock composed of sedimentary carbonate minerals, primarily limestone and dolomite. A reservoir can refer to a pore-cavity structure that serves as a storage space for oil and gas, not distributed in layers but forming irregular combinations within and between layers. A reservoir can also refer to a reservoir within carbonate rocks. Spatial distribution information can include spatial location information and spatial porosity information.

[0033] Specifically, the seismic sensitivity attributes of carbonate reservoirs are determined based on well logging data. Based on these attributes, the seismic sensitivity parameter of the core corresponding to the critical porosity (e.g., 2%) between reservoir and non-reservoir layers is obtained. This parameter serves as the seismic sensitivity threshold for the carbonate reservoir, and its spatial location is determined based on this threshold. A forward model is re-established based on the seismic sensitivity attributes, formation structure, and well logging information. Correction coefficients are determined based on the difference between the simulated seismic response and the actual model volume. The volume of the carbonate reservoir is then determined based on these correction coefficients to obtain a volume close to the actual value. The porosity data volume of the carbonate reservoir is obtained through pre-stack inversion, rock physics analysis, and rock physics modeling. The spatial distribution of porosity information is determined. Based on the spatial location distribution, the determined volume, and the spatial distribution of porosity information, a 3D visualization of pores and cavities is obtained. This 3D visualization is then used as the spatial distribution information of the carbonate reservoir.

[0034] S120. Detect and predict the spatial distribution of fluid in the reservoir to determine the spatial distribution information of fluid in the reservoir.

[0035] The fluid in a storage group can refer to both gases and liquids. For example, fluids can refer to water, natural gas, or oil.

[0036] Specifically, fluid properties are qualitatively detected based on the reservoir's amplitude variation with offset (AVO) and seismic dispersion properties. Constraints from macroscopic geochemical conditions, such as reservoir charging height, hydrocarbon migration path tracing, and reservoir planar charging strength, determined by precise tracing technology throughout the hydrocarbon accumulation process, are used to ensure accurate fluid property detection results. Pre-stack seismic P-wave and S-wave joint inversion is performed on the fluids within the reservoir to obtain P-wave impedance, S-wave impedance, and density volume. Then, a quantitative interpretation standard is established through detailed rock physics modeling, and the reservoir's distribution range is quantitatively determined using the inversion results. The spatial distribution range of the fluids is constrained by the reservoir's distribution range, and the reservoir's distribution range is coupled with fluid detection to determine the spatial distribution information of the fluids within the reservoir.

[0037] S130. Based on the spatial distribution information of the reservoir and the spatial distribution information of carbonate rock fractures, determine the spatial distribution information of carbonate rock fractures and cavities.

[0038] Among them, carbonate rock fissures and cavities can refer to reservoir spaces composed of caves, fissures and dissolution pores of varying sizes.

[0039] Specifically, thresholds are selected using seismic attributes related to carbonate rock fractures to determine the spatial distribution information of carbonate rock fractures. Based on the spatial distribution information of the reservoir and the spatial distribution information of carbonate rock fractures, the spatial distribution information of the reservoir and the spatial distribution information of carbonate rock fractures are fused to determine the spatial distribution information of carbonate rock fractures and cavities.

[0040] For example, S130 may include: dividing the seismic sensitivity attribute values ​​of carbonate rock fractures based on the seismic sensitivity attribute threshold of the fractures to determine the spatial distribution information of carbonate rock fractures; and fusing the spatial distribution information of the reservoir and the spatial distribution information of the fractures to obtain the fused spatial distribution information of carbonate rock fractures and cavities.

[0041] Specifically, the seismic sensitivity attribute value range corresponding to carbonate rock fractures is determined based on the seismic sensitivity attribute threshold of the fractures. The spatial distribution information of carbonate rock fractures is obtained based on this value range. Based on the spatial distribution information of the reservoir, a pore-cavity 3D data volume corresponding to the reservoir spatial distribution, using 3D spatial coordinates (x, y, z) as the position function, is obtained. Similarly, a fracture 3D data volume corresponding to the carbonate rock fracture spatial distribution, also using 3D spatial coordinates (x, y, z), is obtained based on the carbonate rock fracture spatial distribution information. The fracture 3D data volume and the pore-cavity 3D data volume are then fused to obtain a 3D data volume corresponding to the spatial distribution of carbonate rock fractures and cavities. The spatial distribution information of carbonate rock fractures and cavities is then obtained based on this 3D data volume. It should be noted that the 3D data volume refers to a data set using 3D spatial coordinates (x, y, z) as the position function.

[0042] S140. Based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed.

[0043] Specifically, based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, three-dimensional data volumes of fractures and cavities corresponding to the spatial distribution information of fractures and cavities and three-dimensional data volumes of fluids corresponding to the spatial distribution information of fluids are obtained. The three-dimensional data volumes of fractures and cavities and three-dimensional data volumes of fluids are fused in position to determine the spatial distribution information of carbonate oil and gas reservoirs. The fused three-dimensional data volumes are then sculpted in three dimensions. Different rendering methods are used to render and display the spatial distribution information of carbonate oil and gas reservoirs, thereby obtaining a three-dimensional sculpted image of reservoirs and oil and gas reservoirs in carbonate rocks.

[0044] For example, S140 may include: determining the spatial distribution information of carbonate oil and gas reservoirs that meet preset distribution conditions based on fluid spatial distribution information; rendering the spatial distribution information of fractures and vugs based on a first rendering method to display the reservoir spatial distribution in a three-dimensional visualization map; and rendering the oil and gas reservoir spatial distribution information based on a second rendering method different from the first rendering method to display the oil and gas reservoir spatial distribution in a three-dimensional visualization map.

[0045] The preset distribution conditions refer to the pre-defined calibration conditions that the spatial distribution of carbonate oil and gas reservoirs must meet. For example, preset distribution conditions may include: the spatial distribution of oil and gas reservoirs conforming to the calibration rules of oil and gas accumulation paths horizontally, and conforming to the natural differentiation rules of fluids and well data calibration vertically. The first rendering method and the second rendering method refer to two different display styles to clearly distinguish between the spatial distribution of reservoir facies and the spatial distribution of oil and gas reservoirs. For example, the first rendering method may refer to marking the spatial distribution information of fractures and vugs in black and white. The second rendering method may refer to marking the spatial distribution information of carbonate oil and gas reservoirs in color.

[0046] Specifically, based on fluid spatial distribution information, a corresponding three-dimensional fluid data volume is obtained. The three-dimensional data volume of fractures and vugs is then fused with the fluid three-dimensional data volume. Based on the position coordinates in the fused three-dimensional data volume, the spatial distribution information of carbonate oil and gas reservoirs that meets preset distribution conditions is determined. The fused three-dimensional data volume is then sculpted in three dimensions, and different rendering methods are used to render and display the spatial distribution information of carbonate oil and gas reservoirs. For example... Figure 2 As shown, different grayscale values ​​are used to render the spatial distribution information of fractures and voids, displaying the spatial distribution of the reservoir in a 3D visualization; for example... Figure 3 As shown, different colors are used to render the spatial distribution information of oil and gas reservoirs, and the spatial distribution of oil and gas reservoirs is displayed in the three-dimensional visualization map. Thus, the spatial distribution of oil and gas reservoirs in the reservoir can be clearly seen in the three-dimensional visualization map, realizing the visualization and transparency of the spatial distribution of carbonate oil and gas reservoirs, making the drilling target clearer and more distinct.

[0047] The technical solution of this invention determines the spatial distribution information of carbonate reservoirs by spatially locating, quantifying, and quantifying carbonate reservoirs, thereby obtaining reservoir volumes close to actual values ​​and achieving quantitative reservoir characterization. It also detects and predicts the spatial distribution of fluids within the reservoir, obtaining accurate fluid property predictions and spatial distribution information. Based on the spatial distribution information of the reservoir and the spatial distribution information of carbonate fractures, it determines the spatial distribution information of carbonate fractures and vulnerabilities. Based on the spatial distribution information of fractures and vulnerabilities and the spatial distribution information of fluids, it renders and displays the spatial distribution information of carbonate oil and gas reservoirs, thus obtaining a three-dimensional visualized oil and gas reservoir spatial distribution. This achieves three-dimensional transparent and quantitative characterization of deep carbonate oil and gas reservoirs, and further realizes reservoir sculpting based on carbonate reservoir sculpting, making drilling targets clearer and more precise.

[0048] Example 2

[0049] Figure 4 This is a flowchart of a method for displaying the spatial distribution of oil and gas reservoirs according to Embodiment 2 of the present invention. Based on the above embodiments, this embodiment optimizes the step of "spatial positioning, volume determination, and quantitative processing of carbonate reservoirs to determine the spatial distribution information of carbonate reservoirs." Explanations of terms that are the same as or corresponding to those in the above embodiments are not repeated here.

[0050] See Figure 4 The alternative method for displaying the spatial distribution of oil and gas reservoirs provided in this embodiment specifically includes the following steps:

[0051] S210. Determine the seismic sensitivity attribute threshold of the reservoir, and classify the seismic sensitivity attribute values ​​of carbonate rocks based on the seismic sensitivity attribute threshold to determine the initial distribution location information of carbonate rock reservoirs.

[0052] Seismic sensitivity attributes refer to rock physical properties that clearly distinguish reservoirs from non-reservoir layers. It should be noted that a reservoir layer can refer to a rock formation with a core porosity greater than 2%, while a non-reservoir layer can refer to a rock formation with a core porosity less than or equal to 2%.

[0053] Specifically, based on well logging data, the seismic sensitivity attributes of the reservoir are determined. The seismic sensitivity attribute value corresponding to the rock layer with a porosity of 2% is used as the seismic sensitivity attribute threshold of the reservoir. Based on the seismic sensitivity attribute threshold, the seismic sensitivity attribute values ​​of the carbonate rocks are divided, and the reservoir is spatially located based on the seismic sensitivity attribute threshold of the reservoir to determine the initial distribution location information of the carbonate rock reservoir.

[0054] For example, "determining the seismic sensitivity attribute threshold of the reservoir" in S210 may include: obtaining the seismic sensitivity parameter value of the reservoir under each reflection type, wherein the reflection type includes: beaded reflection, sheet reflection and cluttered reflection; comparing the seismic sensitivity parameter values ​​under all reflection types to determine the seismic sensitivity attribute threshold of the reservoir.

[0055] Specifically, by integrating information from seismic data, well logging data, and other sources, the seismic sensitivity parameters for different types of reservoirs—beaded reflections, sheet-like reflections, and chaotic reflections—under seismic waves are determined. The seismic sensitivity parameter values ​​for all reflection types are compared, and the seismic sensitivity attribute values ​​that can distinguish between reservoirs and non-reservoir groups are determined as the seismic sensitivity attribute thresholds for the reservoir groups.

[0056] S220. Determine the volume correction coefficient of the reservoir, and correct the volume of the reservoir under the initial distribution location information based on the volume correction coefficient to obtain the spatial distribution location information of the carbonate reservoir.

[0057] The volume correction factor can be the scaling factor between the seismic characterization of the reservoir obtained from seismic wave reflection and the actual reservoir volume.

[0058] Specifically, a forward model is re-established based on the seismic attributes, stratigraphic structure, and well logging information of the reservoir. Correction coefficients are determined based on the difference between the simulated seismic response results and the actual model volume. The volume of the reservoir under the initial distribution location information is corrected based on the volume correction coefficients to obtain a reservoir volume close to the true value. Based on the spatial location of the reservoir and the corrected reservoir volume, the spatial distribution location information of the carbonate reservoir is obtained.

[0059] S230. Perform porosity quantification on carbonate reservoirs to determine the spatial distribution porosity information of carbonate reservoirs.

[0060] Porosity can be defined as the ratio of the sum of the volumes of all pore spaces in a rock sample to the total volume of the rock sample, and is expressed as a percentage.

[0061] Specifically, based on the geological data of carbonate reservoirs, porosity data volumes corresponding to the reservoirs are obtained using methods such as pre-stack inversion, rock physics analysis, and rock physics modeling. The porosity data volumes are then analyzed, and based on the analysis results, the porosity of the carbonate reservoirs is quantitatively processed to determine the spatial distribution porosity information of the carbonate reservoirs.

[0062] For example, S230 may include: performing reservoir parameter inversion based on post-stack seismic data to obtain reservoir parameter inversion results at each location of the carbonate reservoir; and converting the reservoir parameter inversion results at each location into corresponding porosity based on the conversion relationship between porosity and inversion parameters to obtain spatially distributed porosity information.

[0063] Specifically, based on parameters such as wave impedance, transverse and longitudinal wave velocities, porosity, and resistivity corresponding to the reservoir in the post-stack seismic data, band-limited or broadband inversion is performed on the reservoir parameters to obtain the reservoir parameter inversion results at each location of the carbonate reservoir. The inversion results are analyzed to obtain the original distribution of parameters such as wave impedance underground. Based on the conversion relationship between porosity and inversion parameters, the reservoir parameter inversion results at each location are converted into the corresponding porosity to obtain spatially distributed porosity information.

[0064] S240. Detect and predict the spatial distribution of fluid in the reservoir to determine the spatial distribution information of fluid in the reservoir.

[0065] S250. Based on the spatial distribution information of the reservoir and the spatial distribution information of carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined.

[0066] S260. Based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed.

[0067] The technical solution of this invention determines the seismic sensitivity attribute threshold of the reservoir, classifies the seismic sensitivity attribute values ​​of carbonate rocks based on the seismic sensitivity attribute threshold, obtains the spatial distribution results of carbonate rock reservoirs using seismic sensitivity attributes and seismic inversion, and determines the initial distribution location information of carbonate rock reservoirs; determines the volume correction coefficient of the reservoir, and corrects the volume of the reservoir under the initial distribution location information based on the volume correction coefficient, thereby obtaining spatial distribution location information of carbonate rock reservoirs that is close to the true values; and performs porosity quantification processing on the carbonate rock reservoirs to determine the spatial distribution porosity information of carbonate rock reservoirs, thereby realizing the quantitative characterization of the spatial distribution of carbonate rock reservoirs using porosity data.

[0068] Example 3

[0069] Figure 5 This is a schematic diagram of the structure of an oil and gas reservoir spatial distribution display device provided in Embodiment 3 of the present invention. Figure 5 As shown, the device includes: a storage space distribution determination module 310, a fluid space distribution determination module 320, a slit space distribution determination module 330, and a space distribution display module 340.

[0070] Among them, the reservoir spatial distribution determination module 310 is used to perform spatial positioning, volume determination and quantitative processing of carbonate reservoirs to determine the spatial distribution information of carbonate reservoirs.

[0071] The fluid spatial distribution determination module 320 is used to detect and predict the spatial distribution of fluid in the reservoir, and determine the fluid spatial distribution information in the reservoir.

[0072] The fracture-cavity spatial distribution determination module 330 is used to determine the spatial distribution information of fractures and cavities in carbonate rocks based on the spatial distribution information of reservoirs and the spatial distribution information of fractures in carbonate rocks.

[0073] The spatial distribution display module 340 renders and displays the spatial distribution information of carbonate oil and gas reservoirs based on the spatial distribution information of fractures and caverns and fluid spatial distribution information.

[0074] The technical solution of this embodiment determines the spatial distribution information of carbonate reservoirs by spatially locating, quantifying, and processing the carbonate reservoirs, thereby obtaining a reservoir volume close to the actual value and achieving quantitative characterization of the reservoirs. It also detects and predicts the spatial distribution of fluids within the reservoirs, obtaining relatively accurate fluid property prediction results and fluid spatial distribution information. Based on the spatial distribution information of the reservoirs and the spatial distribution information of carbonate fractures, it determines the spatial distribution information of carbonate fractures and vulcanizations. Based on the spatial distribution information of fractures and vulcanizations and the spatial distribution information of fluids, it renders and displays the spatial distribution information of carbonate oil and gas reservoirs, thus obtaining a three-dimensional visualized oil and gas reservoir spatial distribution. This achieves a three-dimensional transparent and quantitative characterization of deep carbonate oil and gas reservoirs, and further realizes reservoir sculpting based on carbonate reservoir sculpting, making the drilling targets clearer and more precise.

[0075] Optionally, the storage collective spatial distribution determination module 310 includes:

[0076] The initial distribution location determination unit is used to determine the seismic sensitivity attribute threshold of the reservoir, and to divide the seismic sensitivity attribute values ​​of carbonate rocks based on the seismic sensitivity attribute threshold, thereby determining the initial distribution location information of the carbonate rock reservoir.

[0077] The reservoir spatial distribution determination unit is used to determine the volume correction coefficient of the reservoir and correct the volume of the reservoir under the initial distribution location information based on the volume correction coefficient to obtain the spatial distribution location information of the carbonate reservoir.

[0078] The porosity information determination unit is used to perform porosity quantification on carbonate reservoirs and determine the spatial distribution porosity information of carbonate reservoirs.

[0079] Optionally, the initial distribution location determination unit is specifically used to: obtain the seismic sensitivity parameter values ​​of the reservoir under each reflection type, wherein the reflection types include: beaded reflection, sheet reflection and random reflection; compare the seismic sensitivity parameter values ​​under all reflection types, and determine the seismic sensitivity attribute threshold of the reservoir.

[0080] Optionally, the porosity information determination unit is specifically used for: performing reservoir parameter inversion based on post-stack seismic data to obtain reservoir parameter inversion results at each location of the carbonate reservoir; and converting the reservoir parameter inversion results at each location into corresponding porosity based on the conversion relationship between porosity and inversion parameters to obtain spatially distributed porosity information.

[0081] Optionally, the fracture-cavity spatial distribution determination module 330 is specifically used to: classify the seismic sensitivity attribute values ​​of carbonate rock fractures based on the seismic sensitivity attribute threshold of the fractures, and determine the spatial distribution information of carbonate rock fractures; and fuse the spatial distribution information of the reservoir and the spatial distribution information of the fractures to obtain the fused spatial distribution information of carbonate rock fractures and cavities.

[0082] Optionally, the spatial distribution display 340 is specifically used for: determining the spatial distribution information of carbonate oil and gas reservoirs that meet preset distribution conditions based on fluid spatial distribution information; rendering the spatial distribution information of fractures and vugs based on a first rendering method and displaying the reservoir spatial distribution in a three-dimensional visualization map; and rendering the oil and gas reservoir spatial distribution information based on a second rendering method different from the first rendering method and displaying the oil and gas reservoir spatial distribution in a three-dimensional visualization map.

[0083] Optionally, the preset distribution conditions include: the spatial distribution of oil and gas reservoirs conforms to the oil and gas accumulation path calibration law in the horizontal direction, and conforms to the natural differentiation law of fluids and well data calibration in the vertical direction.

[0084] The vehicle network data synchronization device provided in this embodiment of the invention can execute the vehicle network data synchronization method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of executing the method.

[0085] Figure 6 A schematic diagram of an electronic device 12 that can be used to implement embodiments of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as desktop computers, workbenches, servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0086] like Figure 6 As shown, the electronic device 12 is represented in the form of a general-purpose computing device. The components of the electronic device 12 may include, but are not limited to: one or more processors or processing units 16, system memory 28, and bus 18 connecting different system components (including system memory 28 and processing unit 16).

[0087] Bus 18 represents one or more of several bus architectures, including a memory bus or memory controller, a peripheral bus, a graphics acceleration port, a processor, or a local bus using any of the various bus architectures. For example, these architectures include, but are not limited to, the Industry Standard Architecture (ISA) bus, the Micro Channel Architecture (MAC) bus, the Enhanced ISA bus, the Video Electronics Standards Association (VESA) local bus, and the Peripheral Component Interconnect (PCI) bus.

[0088] Electronic device 12 typically includes a variety of computer system readable media. These media can be any available media that can be accessed by electronic device 12, including volatile and non-volatile media, removable and non-removable media.

[0089] System memory 28 may include computer system readable media in the form of volatile memory, such as random access memory (RAM) 30 and / or cache memory 32. Electronic device 12 may further include other removable / non-removable, volatile / non-volatile computer system storage media. By way of example only, storage system 34 may be used to read and write non-removable, non-volatile magnetic media (… Figure 6 Not shown; usually referred to as a "hard drive"). Although Figure 6 Not shown, a disk drive for reading and writing to a removable non-volatile disk (e.g., a "floppy disk") and an optical disk drive for reading and writing to a removable non-volatile optical disk (e.g., a CD-ROM, DVD-ROM, or other optical media) may be provided. In these cases, each drive may be connected to bus 18 via one or more data media interfaces. System memory 28 may include at least one program product having a set (e.g., at least one) of program modules configured to perform the functions of the embodiments of the present invention.

[0090] A program / utility 40 having a set (at least one) of program modules 42 may be stored, for example, in system memory 28. Such program modules 42 include, but are not limited to, an operating system, one or more application programs, other program modules, and program data. Each or some combination of these examples may include an implementation of a network environment. Program modules 42 typically perform the functions and / or methods described in the embodiments of the present invention.

[0091] Electronic device 12 can also communicate with one or more external devices 14 (e.g., keyboard, pointing device, display 24, etc.), and with one or more devices that enable a user to interact with electronic device 12, and / or with any device that enables electronic device 12 to communicate with one or more other computing devices (e.g., network card, modem, etc.). This communication can be performed via input / output (I / O) interface 22. Furthermore, electronic device 12 can also communicate with one or more networks (e.g., local area network (LAN), wide area network (WAN), and / or public networks, such as the Internet) via network adapter 20. As shown, network adapter 20 communicates with other modules of electronic device 12 via bus 18. It should be understood that, although not shown in the figures, other hardware and / or software modules can be used in conjunction with electronic device 12, including but not limited to: microcode, device drivers, redundant processing units, external disk drive arrays, RAID systems, tape drives, and data backup storage systems.

[0092] Processing unit 16 executes various functional applications and data processing by running programs stored in system memory 28, such as implementing the steps of a method for displaying the spatial distribution of oil and gas reservoirs provided in this embodiment, the method including:

[0093] Spatial location, volume determination, and quantitative analysis of carbonate reservoirs were performed to determine their spatial distribution information.

[0094] The fluid in the reservoir is detected and its spatial distribution is predicted to determine the spatial distribution information of the fluid in the reservoir;

[0095] Based on the spatial distribution information of reservoirs and the spatial distribution information of carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined.

[0096] Based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed.

[0097] Of course, those skilled in the art will understand that the processor can also implement the technical solution of the oil and gas reservoir spatial distribution display method provided in any embodiment of the present invention.

[0098] This embodiment provides a computer-readable storage medium storing a computer program thereon. When executed by a processor, the program implements the steps of the oil and gas reservoir spatial distribution visualization method provided in any embodiment of the present invention. The method includes:

[0099] Spatial location, volume determination, and quantitative analysis of carbonate reservoirs were performed to determine their spatial distribution information.

[0100] The fluid in the reservoir is detected and its spatial distribution is predicted to determine the spatial distribution information of the fluid in the reservoir;

[0101] Based on the spatial distribution information of reservoirs and the spatial distribution information of carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined.

[0102] Based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed.

[0103] The computer storage medium of this invention can be any combination of one or more computer-readable media. A computer-readable medium can be a computer-readable signal medium or a computer-readable storage medium. For example, a computer-readable storage medium can be, but is not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples (a non-exhaustive list) of computer-readable storage media include: an electrical connection having one or more wires, a portable computer disk, a hard disk, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fiber, portable compact disk read-only memory (CD-ROM), optical storage device, magnetic storage device, or any suitable combination thereof. In this document, a computer-readable storage medium can be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0104] Computer-readable signal media may include data signals propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals may take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination thereof. Computer-readable signal media may also be any computer-readable medium other than computer-readable storage media, capable of sending, propagating, or transmitting programs for use by or in connection with an instruction execution system, apparatus, or device.

[0105] Program code contained on a computer-readable medium may be transmitted using any suitable medium, including but not limited to: wireless, wire, optical fiber, RF, etc., or any suitable combination thereof.

[0106] Computer program code for performing the operations of this invention can be written in one or more programming languages ​​or a combination thereof. Programming languages ​​include object-oriented programming languages ​​such as Java, Smalltalk, and C++, as well as conventional procedural programming languages—such as the "C" language or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network, including a local area network (LAN) or a wide area network (WAN), or it can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0107] Those skilled in the art will understand that the modules or steps of the present invention described above can be implemented using general-purpose computing devices. They can be centralized on a single computing device or distributed across a network of multiple computing devices. Optionally, they can be implemented using computer-executable program code, thereby allowing them to be stored in a storage device for execution by a computing device, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module. Thus, the present invention is not limited to any particular combination of hardware and software.

[0108] Note that the above description is merely a preferred embodiment of the present invention and the technical principles employed. Those skilled in the art will understand that the present invention is not limited to the specific embodiments described herein, and various obvious changes, readjustments, and substitutions can be made without departing from the scope of protection of the present invention. Therefore, although the present invention has been described in detail through the above embodiments, the present invention is not limited to the above embodiments, and may include many other equivalent embodiments without departing from the concept of the present invention, the scope of which is determined by the scope of the appended claims.

Claims

1. A method for spatially displaying oil and gas reservoirs, characterized in that, include: Spatial location, volume determination, and quantitative analysis of carbonate reservoirs were performed to determine their spatial distribution information. The fluid in the reservoir is detected and its spatial distribution is predicted to determine the spatial distribution information of the fluid in the reservoir. Based on the spatial distribution information of reservoirs and the spatial distribution information of carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined. Based on the spatial distribution information of fractures and cavities and the spatial distribution information of fluids, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed. The process of spatially locating, volumetrically determining, and quantifying carbonate reservoirs to determine their spatial distribution information includes: Based on well logging data, the seismic sensitivity attributes of carbonate reservoirs are determined, and the seismic sensitivity attribute parameters of cores corresponding to the critical porosity between reservoirs and non-reservoirs are obtained according to the seismic sensitivity attributes. The seismic sensitivity attribute parameters are used as the seismic sensitivity attribute thresholds corresponding to carbonate reservoirs, and the carbonate reservoirs are spatially located based on the seismic sensitivity attribute thresholds of the carbonate reservoirs. A forward model is re-established based on the seismic sensitivity attributes, stratigraphic structure, and well logging information of carbonate reservoirs. Correction coefficients are determined based on the difference between the simulated seismic response results and the actual model volume. The volume of carbonate reservoirs is then determined based on the correction coefficients. The porosity data volume of the carbonate reservoir is obtained, and the spatial distribution information of the porosity of the carbonate reservoir is determined. Based on the spatial location distribution information, the volume after quantification, and the spatial distribution information of porosity of the carbonate reservoir, a three-dimensional visualization engraving of pores and cavities is obtained. The three-dimensional visualization engraving of pores and cavities is determined as the spatial distribution information of the carbonate reservoir.

2. The method according to claim 1, characterized in that, Spatial location, volume determination, and quantitative analysis of carbonate reservoirs are performed to determine their spatial distribution information, including: The seismic sensitivity attribute thresholds of the reservoirs are determined, and the seismic sensitivity attribute values ​​of the carbonate rocks are divided based on the seismic sensitivity attribute thresholds to determine the initial distribution location information of the carbonate rock reservoirs. Determine the volume correction factor of the reservoir, and correct the volume of the reservoir under the initial distribution location information based on the volume correction factor to obtain the spatial distribution location information of the carbonate reservoir. Porosity of carbonate reservoirs was quantitatively processed to determine the spatial distribution porosity information of carbonate reservoirs.

3. The method according to claim 2, characterized in that, Determine the seismic sensitivity thresholds for reservoirs, including: Obtain the seismic sensitivity parameter values ​​of the reservoir under each reflection type, wherein the reflection types include: beaded reflection, sheet reflection and cluttered reflection; The seismic sensitivity parameter values ​​under all reflection types are compared to determine the seismic sensitivity attribute threshold of the reservoir.

4. The method according to claim 2, characterized in that, Porosity of carbonate reservoirs was quantitatively analyzed to determine the spatial distribution porosity information of carbonate reservoirs, including: Reservoir parameter inversion was performed based on post-stack seismic data to obtain reservoir parameter inversion results at each location of carbonate reservoirs. Based on the conversion relationship between porosity and inversion parameters, the reservoir parameter inversion results at each location are converted into the corresponding porosity to obtain spatially distributed porosity information.

5. The method according to claim 1, characterized in that, Based on the spatial distribution information of reservoirs and carbonate rock fractures, the spatial distribution information of carbonate rock fractures and cavities is determined, including: Based on the seismic sensitivity attribute threshold of the fracture, the seismic sensitivity attribute values ​​of carbonate rock fractures are divided to determine the spatial distribution information of carbonate rock fractures. The spatial distribution information of the reservoir and the spatial distribution information of the fractures are fused to obtain the spatial distribution information of the carbonate rock fractures and cavities.

6. The method according to claim 1, characterized in that, Based on the spatial distribution information of fractures and cavities and the aforementioned fluid spatial distribution information, the spatial distribution information of carbonate oil and gas reservoirs is rendered and displayed, including: Based on the fluid spatial distribution information, determine the spatial distribution information of carbonate oil and gas reservoirs that meet the preset distribution conditions; Based on the first rendering method, the spatial distribution information of fractures and cavities is rendered, and the spatial distribution of the reservoir is displayed in a three-dimensional visualization map. Based on a second rendering method that differs from the first rendering method, the spatial distribution information of oil and gas reservoirs is rendered, and the spatial distribution of oil and gas reservoirs is displayed in the three-dimensional visualization map.

7. The method according to claim 6, characterized in that, The preset distribution conditions include: the spatial distribution of oil and gas reservoirs conforms to the oil and gas accumulation path calibration law in the horizontal direction, and conforms to the natural differentiation law of fluids and well data calibration in the vertical direction.

8. A device for displaying the spatial distribution of oil and gas reservoirs, characterized in that, include: The module for determining the spatial distribution of carbonate reservoirs is used to perform spatial positioning, volume determination, and quantitative processing of carbonate reservoirs to determine their spatial distribution information. The fluid spatial distribution determination module is used to detect and predict the spatial distribution of fluid in the reservoir, and determine the fluid spatial distribution information in the reservoir. The fracture-cavity spatial distribution determination module is used to determine the spatial distribution information of fractures and cavities in carbonate rocks based on the spatial distribution information of reservoirs and the spatial distribution information of fractures in carbonate rocks. The spatial distribution display module renders and displays the spatial distribution information of carbonate oil and gas reservoirs based on the spatial distribution information of fractures and vulcanizations and the aforementioned fluid spatial distribution information. The reservoir spatial distribution determination module is specifically used for: determining the seismic sensitivity attributes of carbonate reservoirs based on well logging data, and obtaining seismic sensitivity attribute parameters of cores corresponding to the critical porosity between reservoirs and non-reservoirs based on the seismic sensitivity attributes; using the seismic sensitivity attribute parameters as the seismic sensitivity attribute thresholds corresponding to carbonate reservoirs, and spatially locating carbonate reservoirs based on the seismic sensitivity attribute thresholds; re-establishing a forward model based on the seismic sensitivity attributes, formation structure, and well logging information of carbonate reservoirs, determining correction coefficients based on the difference between the simulated seismic response results and the actual model volume, and determining the volume of carbonate reservoirs based on the correction coefficients; obtaining the porosity data volume of carbonate reservoirs, determining the spatial distribution information of porosity of carbonate reservoirs, and obtaining a pore-cavity three-dimensional visualization engraving based on the spatial location distribution information, the determined volume, and the spatial distribution information of porosity of carbonate reservoirs, and determining the pore-cavity three-dimensional visualization engraving as the spatial distribution information of carbonate reservoirs.

9. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the oil and gas reservoir spatial distribution visualization method according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that are used to cause a processor to execute the method for displaying the spatial distribution of oil and gas reservoirs as described in any one of claims 1-7.

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