Method and device for judging reservoir forming condition of stratum and electronic equipment

Abstract

The invention provides a method and device for judging reservoir forming conditions of stratum.The method comprises the steps that a target layer with oil and gas storage capacity is selected, and a hydrocarbon source layer is determined below the target layer; selecting a reference layer between the target layer and the hydrocarbon source layer; respectively determining seismic attribute plane graphs of the target layer, the hydrocarbon source layer and the reference layer; superposing the three seismic attribute plane graphs according to a coordinate system; and according to the superposed seismic attribute plane graph, reservoir forming conditions of the target stratum are judged. According to the scheme, by means of a reference layer, seismic attribute plane graphs of a target layer, a hydrocarbon source layer and the reference layer are stacked according to a coordinate system, and reservoir forming conditions of the target layer are judged according to a stacking result. According to the scheme, the fault reservoir forming condition is determined based on the structural geometry rule, and the fault reservoir forming condition can be quickly and accurately judged according to the three-dimensional matching relation of the hydrocarbon source layer and the target layer; deployment of oil-gas exploration and development well drilling can be effectively guided, and the well drilling success rate is increased.

Description

Technical Field

[0001] This application relates to the technical field of petroleum and natural gas geology, and particularly relates to a method, device, and electronic device for discriminating the hydrocarbon accumulation conditions of strata. Background Art

[0002] Hydrocarbon accumulation refers to the geological process in a sedimentary basin where, after the generation of petroleum and natural gas, they migrate through a carrier bed and finally fill into a trap, aggregating to form an oil and gas reservoir. Faults are important carriers in hydrocarbon accumulation, the main channels for communicating the hydrocarbon source and hydrocarbon migration, and directly control the formation of hydrocarbon traps. Usually, the hydrocarbon migration relationship between the two sides of a relatively small-scale fault is determined based on the contact relationship between the strata on both sides of the fault or the smearing effect of mudstone, so as to determine the hydrocarbon conduction and accumulation effects of the fault. This method cannot accurately discriminate the hydrocarbon accumulation effect of the fault on the three-dimensional structural relationship between the hydrocarbon source layer and the target layer. Even if the two sides of the fault are connected, but there is no communication between the hydrocarbon source layers, hydrocarbon accumulation cannot occur. Therefore, how to accurately and quickly judge the control relationship of the fault on the three-dimensional structure hydrocarbon accumulation of the hydrocarbon source layer and the target layer has important significance and economic value for the trap description of the target layer in oil and gas exploration and development. How to discriminate the influence of faults on the hydrocarbon accumulation conditions of strata has always been a difficulty and key point in oil and gas exploration and development.

[0003] Through patent research, it is found that the patents related to fault hydrocarbon accumulation include "Method for Evaluating the Sealing and Opening Property of Faults Based on Fault Fracture Structure (Application No. CN201611105453.6)", which calculates the opening and closing probability of faults through the permeability of different fault structure parts; "Method and Device for Quantitatively Determining the Three-Dimensional Fault Conduction (Application No. CN 202010903256.9)", which calculates the thickness of the mudstone layer and smearing parameters of the fault surface in a three-dimensional geological model, calculates the distribution thickness of mudstone on the smeared displacement of the fault surface and the fault surface pressure, and obtains the three-dimensional fault surface conduction coefficient; "Method and Device for Determining Fracture Conduction Capacity Parameters (Application No. CN201611095061.6)", which calculates the fault conduction capacity parameters, fracture conduction capacity parameters, and fracture conduction capacity parameters step by step according to the fault mud ratio coefficient and the random sampling number of fractures; and also includes "A Method for Judging Whether Hydrocarbons Can Be Conducted by Using Fault Conduction Probability (Application No. CN202110851135.9)", a method and system for determining the permeability of the fault conduction system (Application No. CN201610452336.0), a method and device for determining fracture conduction capacity parameters (Application No. CN201611095061.6), etc. The above patents involve fault conductivity, but mainly focus on the contact relationship between the two sides of the fault and cannot quickly and accurately discriminate the influence of faults on the hydrocarbon accumulation conditions of strata. Summary of the Invention

[0004] This specification provides a method, apparatus, and electronic device for determining the hydrocarbon accumulation conditions of a formation, aiming to solve the problem that the existing methods cannot quickly and accurately determine the influence of faults on the hydrocarbon accumulation conditions of a formation.

[0005] To solve the above technical problems, a first aspect of this specification provides a method for determining the hydrocarbon accumulation conditions of a formation, including: selecting a target layer with hydrocarbon storage capacity, and determining a source rock layer below the target layer; selecting a reference layer between the target layer and the source rock layer; respectively determining the seismic attribute plane maps of the target layer, the source rock layer, and the reference layer; superimposing the three seismic attribute plane maps according to a coordinate system; and judging the hydrocarbon accumulation conditions of the target layer based on the superimposed seismic attribute plane map.

[0006] In some embodiments, the method further includes: determining a development plan for the target layer according to the hydrocarbon accumulation conditions of the target layer.

[0007] In some embodiments, judging the hydrocarbon accumulation conditions of the target layer based on the superimposed seismic attribute plane map includes: obtaining fault information from the superimposed seismic attribute plane map; if only one of the target layer, the source rock layer, and the reference layer has a fault in the target area, it is determined that the target layer in the target area does not have hydrocarbon accumulation conditions; if only the target layer and the reference layer have faults, or only the reference layer and the source rock layer have faults in the target area, it is determined that the target layer in the target area does not have hydrocarbon accumulation conditions; if the target layer, the source rock layer, and the reference layer all have faults in the target area, it is determined that the target layer in the target area has hydrocarbon accumulation conditions.

[0008] In some embodiments, the target area is an area where the faults are continuous in the seismic attribute plane map of the target layer.

[0009] In some embodiments, three seismic attribute plane maps are superimposed according to a coordinate system, including: setting the fault area in the first seismic attribute plane map of the target layer to a first color, setting the fault area in the second seismic attribute plane map of the reference layer to a second color, setting the fault area in the third seismic attribute plane map of the hydrocarbon source layer to a third color, and setting the non-fault areas in each seismic attribute plane map to a fourth color, where the first color, the second color, the third color, and the fourth color are all different; superimposing the colors of the pixel points at the same coordinate position in the three seismic attribute plane maps, and the first color, the second color, and the third color form a fifth color after superimposition, the first color and the second color form a sixth color after superimposition, the second color and the third color form a sixth color after superimposition, the first color and the fourth color form a seventh color after superimposition, the second color or the third color and the fourth color form the fourth color after superimposition, and the fourth color and the fourth color form the fourth color after superimposition; the fifth color, the sixth color, the seventh color, and the fourth color are all different.

[0010] In some embodiments, according to the superimposed seismic attribute plane map, the hydrocarbon accumulation conditions of the target layer are judged, including: determining that the hydrocarbon accumulation conditions of the target layer in the area shown by the fifth color are good, and the target layer in the areas shown by the sixth color and the seventh color does not have hydrocarbon accumulation conditions.

[0011] In some embodiments, the seismic attribute plane map includes at least one of the following: a coherence attribute plane map, a curvature attribute plane map.

[0012] The second aspect of this specification provides a device for discriminating the hydrocarbon accumulation conditions of a formation, including: a selection unit for selecting a target layer with oil and gas reservoir capacity and determining a hydrocarbon source layer below the target layer; a selection unit for selecting a reference layer between the target layer and the hydrocarbon source layer; a determination unit for respectively determining the seismic attribute plane maps of the target layer, the hydrocarbon source layer, and the reference layer; a superimposition unit for superimposing the three seismic attribute plane maps according to a coordinate system; and a judgment unit for judging the hydrocarbon accumulation conditions of the target layer according to the superimposed seismic attribute plane map.

[0013] The third aspect of this specification provides an electronic device, including: a memory and a processor, the processor and the memory are communicatively connected to each other, the memory stores computer instructions, and the processor realizes the steps of the method according to any one of the first aspects by executing the computer instructions.

[0014] The fourth aspect of this specification provides a computer storage medium, the computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of the method according to any one of the first aspects are realized.

[0015] The method for determining the reservoir-forming conditions of strata provided in this specification determines a hydrocarbon source rock below the target layer, selects a reference layer for auxiliary judgment between the hydrocarbon source rock and the target layer, superimposes the seismic attribute plane maps of the target layer, the hydrocarbon source rock, and the reference layer according to the coordinate system, and determines the reservoir-forming conditions of the target layer based on the superimposed result, that is, determines whether there is a fault connecting the hydrocarbon source rock and the target layer, so that the oil and gas in the hydrocarbon source rock can be diverted to the target layer. This solution determines the fault reservoir-forming conditions based on the laws of structural geometry, can quickly and accurately determine the fault reservoir-forming conditions from the three-dimensional matching relationship between the hydrocarbon source rock and the target layer, can effectively guide the deployment of oil and gas exploration and development wells, and improve the success rate of well drilling. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the following will briefly introduce the drawings required for the description of the embodiments or the prior art. Obviously, the drawings in the following description are only some embodiments recorded in the present application. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained based on these drawings.

[0017] Figure 1 It is a flowchart of the method for determining the reservoir-forming conditions of strata provided in this specification;

[0018] Figure 2 It is a schematic diagram for determining the reservoir-forming conditions of the target layer based on the superimposed seismic attribute plane map;

[0019] Figure 3 It is a coherence attribute plane map of the P3 hydrocarbon source rock;

[0020] Figure 4 It is a coherence attribute plane map of the P2 reference layer;

[0021] Figure 5 It is a coherence attribute plane map of the P1 target layer;

[0022] Figure 6 It is Figure 3 and Figure 4 and Figure 5 The result of superimposing the coherence attribute plane maps shown according to the coordinates;

[0023] Figure 7 It is Figure 6 A schematic diagram of the result of further processing the superimposing operation in;

[0024] Figure 8 It is a cross-sectional view at the A fault in the superimposed coherence attribute plane map;

[0025] Figure 9 It is a cross-sectional view at the B fault in the superimposed coherence attribute plane map;

[0026] Figure 10 It is a cross-sectional view at Fault C in the coherent attribute plane map after superposition;

[0027] Figure 11 It is a schematic diagram of the device for discriminating the reservoir formation conditions provided in this specification;

[0028] Figure 12 It is a schematic structural diagram of the electronic device provided in this specification. Specific implementation manners

[0029] In order to enable those skilled in the art to better understand the technical solutions in this application, the technical solutions in the embodiments of this application will be clearly and completely described below in conjunction with the accompanying drawings in the embodiments of this application. Obviously, the described embodiments are only a part of the embodiments of this application, rather than all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by those of ordinary skill in the art without making creative efforts shall fall within the protection scope of this application.

[0030] How to accurately judge the role of faults in the conduction and communication of reservoir formation is very important for the exploration and development of oil and gas. Whether in the exploration and development of oil and gas in compressive structures, extensional structures, or strike-slip structures, faults are inevitable structural phenomena to be encountered. The control of underground fault reservoir formation can only be predicted and judged based on seismic data. However, the traditional method of analyzing the relationship between the two fault blocks using seismic data cannot discriminate the three-dimensional control effect of faults on the oil and gas system. Therefore, it is necessary to constrain the seismic data based on the laws of structural geometry to determine the control effect of faults on oil and gas reservoir formation. The influence of underground faults on the reservoir formation conditions of strata can only be predicted and judged macroscopically based on seismic data. However, the traditional method of analyzing the relationship between the two fault blocks using seismic data cannot discriminate the three-dimensional control effect of faults on the oil and gas system.

[0031] This specification constrains seismic data based on the laws of structural geometry to determine the control effect of faults on oil and gas reservoir formation.

[0032] This specification provides a method for discriminating the reservoir formation conditions of strata, as Figure 1 shown, the method includes the following steps:

[0033] S10: Select a target layer with oil and gas storage capacity, and determine a source rock layer below the target layer.

[0034] The target layer refers to the reservoir layer of oil and gas, which is a stratum with the ability to store oil and natural gas. The method for determining the target layer with oil and gas storage capacity exists in the prior art and will not be elaborated in this application.

[0035] A source rock layer refers to a layer with hydrocarbon generation ability, that is, a formation that can form petroleum and natural gas. The methods for determining the source rock layer also exist in the prior art and will not be elaborated in this application.

[0036] S20: Select a reference layer between the target layer and the source rock layer.

[0037] First, the target layer and the source rock layer can be determined in the seismic profile of the research area, and then a reference layer located between the target layer and the source rock layer can be selected within the seismic profile.

[0038] The reference layer is used to refer to whether the fault communicates and connects the source rock layer and the target layer.

[0039] In some embodiments, only one reference layer can be selected, and based on this reference layer, the method provided in this specification for discriminating the reservoir-forming conditions of the formation can be used to determine the reservoir-forming conditions of the target layer.

[0040] In some embodiments, multiple reference layers can also be selected. The method provided in this specification for discriminating the reservoir-forming conditions of the formation is used respectively according to each reference layer to determine the reservoir-forming conditions of the target layer, and finally the reservoir-forming conditions of the target layer are comprehensively determined based on the reservoir-forming conditions of each reference layer determined. For example, the determination results of the reservoir-forming conditions corresponding to most of the reference layers are used as the final determination results.

[0041] S30: Determine the seismic attribute plane maps of the target layer, the source rock layer, and the reference layer respectively.

[0042] The seismic attribute plane map can be a coherence attribute plane map or a curvature attribute plane map, or a similar seismic attribute plane map.

[0043] The method for determining the seismic attribute plane map of a formation exists in the prior art and will not be elaborated in this specification.

[0044] S40: Superimpose the three seismic attribute plane maps according to the coordinate system.

[0045] Each seismic attribute plane map includes the abscissa and ordinate (such as longitude and latitude) for representing the geographical space, and the seismic attribute values at the coordinate points determined by the abscissa and ordinate. Superimposing the three seismic attribute plane maps according to the coordinate system means superimposing the seismic attribute values at the same coordinate points in the three seismic attribute plane maps to obtain a value, and using this value as the superimposed value.

[0046] S50: Judge the reservoir-forming conditions of the target layer according to the superimposed seismic attribute plane map.

[0047] After determining the superimposed seismic attribute plan view, fault information can be obtained therefrom, and then the hydrocarbon accumulation conditions of the target layer can be judged based on the fault information. Then, according to the hydrocarbon accumulation conditions of the target layer, a development plan for the target layer is determined. For example, if the hydrocarbon accumulation conditions of the target layer are good, drilling towards the target layer can better achieve the exploitation of the oil and gas reservoir.

[0048] In the case where the seismic attribute plan view is a coherence attribute plan view, since the main principle of the coherence technique is to represent the lateral inhomogeneity of the formation by the similarity of adjacent seismic trace signals in the 3D seismic data volume, so as to determine the faults in the formation. Therefore, the information of the faults communicating between any two formations can be determined in the superimposed coherence attribute plan view, and then the hydrocarbon accumulation conditions of the target layer can be judged based on the communication effect of the faults among the three formations.

[0049] In the case where the seismic attribute plan view is a curvature attribute plan view, since curvature is used to reflect the degree of bending of a geometric body, describing the degree of perfection of any point on a curve and indicating the degree of deviation of the curve from a straight line. The greater the curvature, the greater the degree of bending of the curve. In structural interpretation, the curvature can be calculated based on the interpretation data of the horizon, so that its structural characteristics can be quantitatively described. After smoothing, the fault can be approximately considered to have a change in curvature from positive to negative or from negative to positive. Therefore, the fault information can be determined from the curvature change in the curvature attribute plan view, and thus the information of the faults communicating between any two formations can be determined in the superimposed curvature attribute plan view, and then the hydrocarbon accumulation conditions of the target layer can be judged based on the communication effect of the faults among the three formations.

[0050] As Figure 2 shown, step S50 may include the following steps S51, S52, S53 and S54.

[0051] S51: Obtain fault information according to the superimposed seismic attribute plan view.

[0052] S52: If only one of the target layer, the source rock layer, and the reference layer in the target area has a fault, it is determined that the target layer in the target area does not have hydrocarbon accumulation conditions.

[0053] S53: If only the target layer and the reference layer in the target area have faults, or only the reference layer and the source rock layer have faults, it is determined that the target layer in the target area does not have hydrocarbon accumulation conditions.

[0054] S54: If the target layer, the source rock layer, and the reference layer in the target area all have faults, it is determined that the target layer in the target area has hydrocarbon accumulation conditions.

[0055] The target area here can be a relatively small area. For example, the target area can be the area where a fault is located, or the target area is the area where the faults are continuous in the seismic attribute plan view of the target formation.

[0056] In some embodiments, S40 includes S41 and S42.

[0057] S41: Set the fault area in the first seismic attribute plan view of the target formation to the first color, set the fault area in the second seismic attribute plan view of the reference formation to the second color, set the fault area in the third seismic attribute plan view of the source rock formation to the third color, and set the non-fault areas in each seismic attribute plan view to the fourth color. The first color, the second color, the third color, and the fourth color are all different.

[0058] S42: Superimpose the colors of the pixel points at the same coordinate position in the three seismic attribute plan views. The superposition of the first color, the second color, and the third color forms the fifth color. The superposition of the first color and the second color forms the sixth color. The superposition of the second color and the third color forms the sixth color. Only one of the first color, the second color, and the third color forms the seventh color when superimposed with the fourth color, and the superposition of the fourth color and the fourth color remains the fourth color. The fifth color, the sixth color, the seventh color, and the fourth color are all different.

[0059] Correspondingly, S50 can be: Determine that the reservoir-forming conditions of the target formation in the area shown by the fifth color (i.e., corresponding to the situation where there are faults in the target formation, the source rock formation, and the reference formation in the target area) are good, and the reservoir-forming conditions of the target formation in the areas shown by the sixth color (i.e., corresponding to the situation where there are only faults in the target formation and the reference formation, or only in the reference formation and the source rock formation in the target area) and the seventh color (i.e., corresponding to the situation where there is only one layer with a fault among the target formation, the source rock formation, and the reference formation in the target area) are not available.

[0060] For example, Figure 3 is the coherence attribute plan view of the P3 source rock formation, Figure 4 is the coherence attribute plan view of the P2 reference formation, Figure 5 is the coherence attribute plan view of the P1 target formation, Figure 6 is Figure 3 、 Figure 4 、 Figure 5 The result of superimposing the coherence attribute plan views shown by coordinate. In Figure 6 , the straight lines shown by A, B, and C represent three sets of faults. Figure 7 is Figure 6 The schematic diagram of the result after further processing of the superimposing operation in.

[0061] When using the method provided in this specification to determine the hydrocarbon accumulation conditions of a formation, the upper target layer P3, the middle reference layer P2, and the lower source rock layer P1 can be selected according to the formation profile information first; then the coherence attribute plane maps of these three formations are determined respectively. The fault information of the upper target layer P3 is represented by blue (i.e., the first color) (as Figure 3 shown), the fault information of the middle reference layer P2 is represented by red (i.e., the second color) (as Figure 4 shown), the fault information of the lower source rock layer P1 is represented by black (i.e., the third color) (as Figure 5 shown), and the non-fault information can be set to white or transparent (the white or transparent color here can be called the background color, i.e., the fourth color). Figure 3 , Figure 4 , Figure 5 are directly superimposed according to the coordinate system to obtain Figure 6 . Further process Figure 6 , set the color of the coordinate positions where blue, red, and black are superimposed to black (i.e., the fifth color), set the color of the coordinate positions where blue and red are superimposed, or where red and black are superimposed to dark gray (i.e., the sixth color), set the color of the coordinate positions where only blue is superimposed to light gray (i.e., the seventh color), set the color of the coordinate positions where only red or blue is superimposed to the background color, and the background color remains the background color when superimposed with the background color.

[0062] To verify the effectiveness of the method provided in this specification for determining the hydrocarbon accumulation conditions of a formation, this specification provides the cross-sectional views at Fault A (as Figure 6 shown), Fault B (as Figure 8 shown), and Fault C (as Figure 9 shown) in the superimposed coherence attribute plane map shown in Figure 10 . In Figure 8 , Figure 9 and Figure 10 , the P3 formation represented by the yellow curve is the target layer, the P2 formation represented by the pink curve is the reference layer, the P1 formation represented by the blue curve is the source rock layer, and the red curve represents the corresponding fault. Figures 8 to 10 The horizontal scale in

[0063] is 650m and the vertical scale is 85ms. Figure 6 As shown in Figure 8 , in the area where Fault A is located, fault information is shown in the coherence attribute plane maps of the target layer P3, the reference layer P2, and the source rock layer P1. Corresponding to the cross-sectional view of the formation shown in Figure 7Among them, the accumulation conditions of the target layer in the area represented by black are good.

[0064] As Figure 6 shown, in the area where Fault B is located, fault information is shown in the coherence attribute plan view of the target layer P3 and the reference layer P2, and no fault information is shown in the coherence attribute plan view of the source rock layer P1. Corresponding to Figure 9 the stratigraphic cross-section shown, the faults of the target layer P3 and the reference layer P2 are connected, but there is no fault in the source rock layer P1, indicating poor fault conduction, and the oil and gas in the source rock layer P1 cannot be conducted to the target layer P3. Therefore, the accumulation conditions of the target layer are good. Corresponding to Figure 7 Among them, the accumulation conditions of the target layer in the area represented by dark gray are poor and do not have the accumulation conditions.

[0065] As Figure 6 shown, in the area where Fault C is located, only the coherence attribute plan view of the target layer P3 shows fault information, and no fault information is shown in the coherence attribute plan views of the reference layer P2 and the source rock layer P1. Corresponding to Figure 10 the stratigraphic cross-section shown, neither the reference layer P2 nor the source rock layer P1 has a fault connected to the target layer P3, indicating no fault conduction, and the oil and gas in the source rock layer P1 cannot be conducted to the target layer P3. Therefore, the accumulation conditions of the target layer are poor. Corresponding to Figure 7 Among them, the accumulation conditions of the target layer in the area represented by light gray are poor and do not have the accumulation conditions.

[0066] This specification provides a device for discriminating the accumulation conditions of strata, which can be used to implement the above discrimination of the accumulation conditions of strata. As Figure 11 shown, the device includes a selection unit 10, a selection unit 20, a determination unit 30, a superposition unit 40, and a judgment unit 50.

[0067] The selection unit 10 is used to select a target layer with oil and gas accumulation capacity and determine a source rock layer below the target layer.

[0068] The selection unit 20 is used to select a reference layer between the target layer and the source rock layer.

[0069] The determination unit 30 is used to respectively determine the seismic attribute plan views of the target layer, the source rock layer, and the reference layer.

[0070] The superposition unit 40 is used to superpose the three seismic attribute plan views according to the coordinate system.

[0071] The judgment unit 50 is used to judge the accumulation conditions of the target layer according to the superposed seismic attribute plan view.

[0072] The descriptions and functions of the above devices can be understood by referring to the content of the method part for discriminating the accumulation conditions of strata, and will not be elaborated here.

[0073] An embodiment of the present invention further provides an electronic device, such as Figure 12 shown, the electronic device may include a processor 1201 and a memory 1202, wherein the processor 1201 and the memory 1202 may be connected by a bus or other means, Figure 12 taking the connection by bus as an example.

[0074] The processor 1201 may be a central processing unit (CPU). The processor 1201 may also be other general-purpose processors, digital signal processors (DSPs), application specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. chips, or combinations of the above types of chips.

[0075] The memory 1202, as a non-transitory computer-readable storage medium, can be used to store non-transitory software programs, non-transitory computer-executable programs, and modules, such as the program instructions / modules corresponding to the method for discriminating formation hydrocarbon accumulation conditions in the embodiments of the present invention (for example, Figure 11 shown, the selected unit 10, the selection unit 20, the determination unit 30, the superposition unit 40, and the judgment unit 50). The processor 1201 executes various functional applications and data processing of the processor by running the non-transitory software programs, instructions, and modules stored in the memory 1202, that is, implements the method for discriminating formation hydrocarbon accumulation conditions in the above method embodiments.

[0076] The memory 1202 may include a program storage area and a data storage area. Among them, the program storage area may store an operating system and application programs required for at least one function; the data storage area may store data created by the processor 1201, etc. In addition, the memory 1202 may include high-speed random access memory, and may also include non-transitory memory, such as at least one magnetic disk storage device, a flash memory device, or other non-transitory solid-state storage devices. In some embodiments, the memory 1202 may optionally include a memory remotely provided with respect to the processor 1201, and these remote memories may be connected to the processor 1201 through a network. Examples of the above networks include, but are not limited to, the Internet, an enterprise internal network, a local area network, a mobile communication network, and combinations thereof.

[0077] The one or more modules are stored in the memory 1202 and, when executed by the processor 1201, perform the foregoing method for determining the formation hydrocarbon accumulation conditions.

[0078] Specific details of the above electronic device can be understood by referring to the corresponding relevant descriptions and effects in the method embodiments, and will not be elaborated here.

[0079] This specification also provides a computer storage medium storing computer program instructions, which when executed, implement the steps of the above method for determining the formation hydrocarbon accumulation conditions.

[0080] This specification also provides a computer program product including a computer program, which when executed by a processor, implements the steps of the above method for determining the formation hydrocarbon accumulation conditions.

[0081] Those skilled in the art can understand that all or part of the processes in the above method embodiments can be completed by instructing relevant hardware through a computer program. The program can be stored in a computer-readable storage medium. When the program is executed, it can include the processes of the above method embodiments. Among them, the storage medium can be a magnetic disk, an optical disc, a read-only memory (ROM), a random access memory (RAM), a flash memory, a hard disk drive (HDD), or a solid-state drive (SSD), etc.; the storage medium can also include a combination of the above types of memories.

[0082] Each embodiment in this specification is described in a progressive manner. The same or similar parts between the embodiments can be referred to each other, and the differences between each embodiment and other embodiments are emphasized.

[0083] The systems, devices, modules, or units described in the above embodiments can be specifically implemented by computer chips or entities, or by products with certain functions.

[0084] For convenience of description, when describing the above device, various units are described separately according to functions. Of course, when implementing the present application, the functions of each unit can be implemented in one or more software and / or hardware.

[0085] From the description of the above embodiments, those skilled in the art can clearly understand that the present application can be implemented by means of software plus a necessary general hardware platform. Based on such an understanding, the technical solution of the present application, in essence, or the part that makes a contribution to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) to execute the methods of certain parts of various embodiments of the present application.

[0086] The present application can be used in numerous general-purpose or special-purpose computer system environments or configurations. For example: personal computers, server computers, handheld or portable devices, tablet devices, multi-processor systems, microprocessor-based systems, set-top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments including any of the above systems or devices, and so on.

[0087] The present application can be described in the general context of computer-executable instructions executed by a computer, such as program modules. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform specific tasks or implement specific abstract data types. The present application can also be practiced in a distributed computing environment, where tasks are performed by remote processing devices connected through a communication network. In a distributed computing environment, program modules can be located in local and remote computer storage media including storage devices.

[0088] Although the present application is depicted through embodiments, those of ordinary skill in the art know that the present application has many variations and changes without departing from the spirit of the present application. It is hoped that the appended claims will cover these variations and changes without departing from the spirit of the present application.

Claims

1. A method for determining formation reservoir conditions. It is characterized in that include: Selecting a target layer with oil and gas storage capacity, and determining a source layer below the target layer; Selecting a reference layer between the target layer and the source layer; respectively determining the seismic attribute plane maps of the target layer, the source layer, and the reference layer; Overlay the three seismic attribute planes according to the coordinate system; The reservoir-forming conditions of the target layer are determined based on the superimposed seismic attribute plane map.

2. The method according to claim 1, It is characterized in that The method further comprises: A development plan for the target layer is determined based on the reservoir-forming conditions of the target layer.

3. The method according to claim 1, It is characterized in that According to the superimposed seismic attribute plane map, the reservoir formation conditions of the target layer are judged, including: Obtain fault information based on the superimposed seismic attribute plane map; If only one of the target layer, the source layer, and the reference layer in the target area has a fault, it is determined that the target layer in the target area does not have the conditions for reservoir formation; If only the target layer and the reference layer have faults in the target area, or only the reference layer and the source layer have faults, it is determined that the target layer in the target area does not have reservoir formation conditions; If the target layer, the source layer and the reference layer in the target area all have faults, it is determined that the target layer in the target area has the conditions for reservoir formation.

4. The method according to claim 3, It is characterized in that The target area is an area where faults are continuous in the seismic attribute plane diagram of the target layer.

5. The method according to claim 1, It is characterized in that Overlay three seismic attribute planes according to the coordinate system, including: Setting the fault region in the first seismic attribute plane map of the target layer to a first color, setting the fault region in the second seismic attribute plane map of the reference layer to a second color, setting the fault region in the third seismic attribute plane map of the source layer to a third color, and setting the non-fault region in each seismic attribute plane map to a fourth color, wherein the first color, the second color, the third color, and the fourth color are different from each other; The colors of the pixel points at the same coordinate position in the three seismic attribute plane maps are superimposed, and the first color, the second color, and the third color are superimposed to form a fifth color, the first color and the second color are superimposed to form a sixth color, the second color and the third color are superimposed to form a sixth color, and the first color and the fourth color are superimposed to form a seventh color; the fifth color, the sixth color, the seventh color, and the fourth color are different.

6. The method according to claim 5, It is characterized in that According to the superimposed seismic attribute plane map, the reservoir formation conditions of the target layer are judged, including: It is determined that the target layer in the area indicated by the fifth color has good reservoir-forming conditions, while the target layer in the areas indicated by the sixth color and the seventh color does not have the reservoir-forming conditions.

7. The method according to claim 1, It is characterized in that The seismic attribute plane map includes at least one of the following: a coherence attribute plane map and a curvature attribute plane map.

8. A device for determining formation reservoir conditions, It is characterized in that include: A selection unit is used to select a target layer with oil and gas storage capacity and determine a source layer below the target layer; A selection unit, used for selecting a reference layer between the target layer and the source layer; A determination unit, used to respectively determine the seismic attribute plane maps of the target layer, the source layer, and the reference layer; The superposition unit is used to superimpose three seismic attribute plane maps according to the coordinate system; The judging unit is used to judge the reservoir-forming conditions of the target layer according to the superimposed seismic attribute plane map.

9. An electronic device, It is characterized in that include: A memory and a processor, wherein the processor and the memory are communicatively connected to each other, the memory stores computer instructions, and the processor implements the steps of the method according to any one of claims 1 to 7 by executing the computer instructions.

10. A computer storage medium, It is characterized in that The computer storage medium stores computer program instructions, and when the computer program instructions are executed, the steps of the method according to any one of claims 1 to 7 are implemented.

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