Reservoir plane distribution feature fine description method and device based on landform control, medium and equipment

Abstract

The invention discloses a reservoir plane distribution feature fine description method based on landform control, and the method comprises the steps: carrying out fine well-seismic calibration based on three-dimensional seismic data and well-seismic combination, and tracking and explaining a top interface and a bottom interface of a target reservoir; calculating an initial reservoir sensitive seismic attribute; obtaining a target reservoir deposition ancient landform; according to the fine well-seismic calibration time-depth relation, the current terrain of the target reservoir is obtained; and correcting the initial reservoir sensitive seismic attribute according to the target reservoir sedimentary ancient landform and the current terrain of the target reservoir to obtain a final target reservoir sensitive seismic attribute, and compiling a target reservoir sedimentary facies map according to the final target reservoir sensitive seismic attribute. Aiming at the reservoir characteristic analysis uncertainty caused by strong reflection of the substrate and the gas-bearing reservoir, the method for correcting the sensitive seismic attributes of the reservoir by adopting the ancient landform and the current topography is adopted, the reservoir response error information caused by strong reflection of the substrate and the gas-bearing reservoir is eliminated, the reservoir characterization precision is improved, and the reservoir analysis uncertainty is effectively reduced.

Description

Technical Field

[0001] The present invention belongs to the technical field of geological research on offshore oilfield development, and in particular relates to a method, device, medium and equipment for finely depicting reservoir plane distribution characteristics based on landform control. Background Art

[0002] In the field of oil and gas exploration and development, the analysis of reservoir characteristics is crucial for the effective development and utilization of resources. Reservoir characteristics encompass multiple key aspects, including the reservoir's planar and spatial geometry, planar and spatial scale, continuity, connectivity, internal structure, pore characteristics, and the distribution of reservoir physical properties. Furthermore, the distribution of interlayers is an essential factor in reservoir characterization. Analysis of the planar distribution of reservoir characteristics is a crucial foundational task in oil and gas exploration and development, and its accuracy directly impacts numerous subsequent steps, including the formulation of oil and gas field development plans.

[0003] Currently, the industry primarily uses a "point-line-surface" approach to analyze reservoir planar distribution characteristics. Specifically, starting with cores and logging curves at well points, single-well reservoir characteristics analysis is conducted to obtain basic reservoir information at individual well locations. Then, inter-well reservoir comparative analysis is conducted by selecting connected well profiles within the study area. By comparing reservoir characteristics between adjacent wells, a preliminary concept of reservoir connectivity and variation patterns between wells is established. Finally, combined with seismic attributes, a well-seismic integration approach is used to manually delineate existing seismic attribute bodies based on researchers' geological understanding, completing the analysis of reservoir planar distribution, aiming to depict the planar distribution of reservoirs within the study area.

[0004] However, this traditional method for analyzing reservoir planar distribution characteristics has many limitations. Its analysis accuracy is largely limited by the number of wells drilled in the study area and the researchers' experience in interpreting seismic attributes. When the number of wells drilled in the study area is limited, the acquired well point data is relatively sparse, making it difficult to fully and accurately reflect the true characteristics of the reservoir, which in turn affects the accuracy of single-well reservoir characteristic analysis and inter-well comparative analysis. At the same time, researchers' experience in interpreting seismic attributes varies, and when manually delineating seismic attribute bodies, they rely too much on the subjective judgment of technicians, which makes the analysis results prone to deviations. Especially when the number of wells drilled is small and the number of sampling points is small, the differences in the technical skills of technicians may lead to low mapping accuracy, and ultimately make it difficult to ensure the accuracy of identifying reservoir planar distribution characteristics.

[0005] In the early stages of offshore oil and gas field exploration and development, well patterns are typically sparse, with well spacing typically exceeding 1,000 meters. Even in the mid- to late-stage, where well spacing can reach 200 to 500 meters in some areas, the overall well density remains relatively low compared to onshore fields. Under these sparse well patterns, existing reservoir planar distribution feature analysis methods struggle to meet the precision requirements of offshore oil and gas field development. This is particularly true for gas-bearing reservoirs, where large amplitude variations lead to unclear internal reservoir characteristics, further complicating the analysis of reservoir planar distribution features and exposing significant challenges and shortcomings to traditional analysis methods in offshore fields.

[0006] In view of the many problems and shortcomings of the above-mentioned existing technologies, there is an urgent need for a new method that can fully utilize three-dimensional seismic data and drilled well data, overcome the limitations of traditional methods, and effectively improve the accuracy of reservoir planar distribution feature analysis to meet the exploration and development needs of various oil and gas fields, including offshore oil and gas fields, especially in complex situations such as gas-bearing reservoirs, to achieve a detailed characterization of the reservoir planar distribution characteristics. Summary of the Invention

[0007] The present invention aims to solve at least one of the technical problems existing in the prior art. To this end, the present invention provides a method for finely characterizing the planar distribution of reservoirs based on topographic control, aiming to fully utilize three-dimensional seismic data to perform fine characterization of the planar distribution of reservoirs under sparse offshore well patterns.

[0008] To achieve the above object, the present invention adopts the following technical solutions:

[0009] In a first aspect, the present invention provides a method for finely characterizing reservoir planar distribution characteristics based on landform control, comprising the following steps:

[0010] Based on 3D seismic data, we combine well and seismic data to conduct fine well-seismic calibration and track and interpret the top and bottom interfaces of the target reservoir;

[0011] Based on 3D seismic data and the top and bottom interfaces of the target reservoir, the initial reservoir sensitive seismic attributes are obtained;

[0012] Obtain target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir;

[0013] Based on the top and bottom interfaces of the target reservoir and the time-depth relationship of fine well-seismic calibration, the current topography of the target reservoir is obtained;

[0014] According to the target reservoir sedimentary paleogeomorphology and the target reservoir present topography, the initial reservoir sensitive seismic attributes are corrected to obtain the final target reservoir sensitive seismic attributes, and the target reservoir sedimentary facies map is compiled based on the final target reservoir sensitive seismic attributes.

[0015] Preferably, the three-dimensional seismic data includes geological data, seismic data and well logging data.

[0016] As an example, the “determining initial reservoir sensitive seismic attributes based on 3D seismic data and the top and bottom interfaces of the target reservoir” is specifically as follows:

[0017] Taking the top and bottom interfaces of the target reservoir as seismic time windows, the seismic attributes of the target reservoir are extracted based on 3D seismic data;

[0018] Taking the top and bottom interfaces of the target reservoir as constraints, calculate the actual drilling sand body thickness of the target reservoir;

[0019] A correlation analysis is performed on the extracted target reservoir seismic attributes and the actual drilling sand body thickness of the target reservoir to obtain the initial reservoir sensitive seismic attributes.

[0020] As an example, the “obtaining target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir” is specifically as follows:

[0021] Taking the top and bottom interfaces of the target reservoir as constraints, the primary paleo-geomorphology of the target reservoir is obtained by calculating the difference between the top and bottom interfaces of the target reservoir;

[0022] Based on the acquired primary paleo-geomorphology of the target reservoir, the paleo-geomorphology of the target reservoir after removing the influence of faults is obtained by removing outliers and constraining geological knowledge;

[0023] Based on the obtained target reservoir paleo-geomorphology after removing the influence of faults, the compaction-corrected paleo-geomorphology is obtained as the target reservoir sedimentary paleo-geomorphology.

[0024] As a preferred embodiment, the “obtaining the current topography of the target reservoir based on the top and bottom interfaces of the target reservoir and the time-depth relationship of fine well-seismic calibration” is specifically:

[0025] Taking the top interface of the target reservoir as a constraint, obtain the time domain structural data of the top interface of the target reservoir;

[0026] Based on the time-depth relationship obtained from fine well-seismic calibration, a multi-well time-depth fitting method is used to obtain the time-depth relationship of the structural surface in the time domain and the structural surface in the depth domain.

[0027] Based on the acquired time-domain structural data of the top interface of the target reservoir and the time-depth relationship between the conversion of the time-domain structural surface and the depth-domain structural surface, the structural data of the top interface of the target reservoir are obtained as the current topography of the target reservoir.

[0028] As a preferred embodiment, the method of “correcting the initial reservoir sensitive seismic attributes to obtain the final target reservoir sensitive seismic attributes based on the target reservoir sedimentary paleogeomorphology and the target reservoir present-day topography, and compiling the target reservoir sedimentary facies map based on the final target reservoir sensitive seismic attributes” is specifically as follows:

[0029] Normalize the acquired target reservoir sedimentary paleogeomorphology to obtain the paleogeomorphological correction factor of the initial reservoir sensitive seismic attributes;

[0030] Multiplying the initial reservoir sensitive seismic attributes and the paleo-geomorphology correction factor to obtain the target reservoir sensitive seismic attributes after paleo-geomorphology constraint correction;

[0031] Based on the acquired current topography of the target reservoir and the actual drilling gas layer depth, the gas-bearing boundary is obtained, and the sensitive seismic attributes of the target reservoir within the gas-bearing influence range are delineated accordingly; the actual drilling gas layer depth is obtained based on the well logging interpretation results;

[0032] Based on actual drilling fluid data and combined with forward model analysis, the gas reservoir correction factor of the sensitive seismic attributes of the target reservoir is obtained;

[0033] Multiply the obtained sensitive seismic attributes of the target reservoir within the gas-bearing influence range by the gas-bearing reservoir correction factor to obtain the sensitive seismic attributes of the target reservoir after correction for the current terrain constraints;

[0034] The sensitive seismic attributes of the target reservoir corrected by paleo-geomorphic constraints are merged with the sensitive seismic attributes of the target reservoir corrected by current topography constraints to obtain the final sensitive seismic attributes of the target reservoir;

[0035] Based on the obtained sensitive seismic attributes of the final target reservoir and combined with the sedimentary facies knowledge from actual drilling, a sedimentary facies map of the target reservoir is compiled.

[0036] In a second aspect, the present invention provides a device for finely depicting reservoir planar distribution characteristics based on landform control, comprising:

[0037] The first processing unit is used to carry out fine well-seismic calibration based on 3D seismic data and the combination of well and seismic data, and to track and interpret the top and bottom interfaces of the target reservoir;

[0038] The second processing unit is used to obtain initial reservoir sensitive seismic attributes based on the three-dimensional seismic data and the top and bottom interfaces of the target reservoir;

[0039] The third processing unit is used to obtain the target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir;

[0040] The fourth processing unit is used to obtain the current topography of the target reservoir based on the top and bottom interfaces of the target reservoir and the time-depth relationship of the fine well-seismic calibration;

[0041] The fifth processing unit is used to correct the initial reservoir sensitive seismic attributes according to the target reservoir sedimentary paleo-geomorphology and the target reservoir current topography to obtain the final target reservoir sensitive seismic attributes, and compile the target reservoir sedimentary facies map according to the final target reservoir sensitive seismic attributes.

[0042] In a third aspect, the present invention provides a computer-readable storage medium storing a computer program, wherein the computer program is executed by a processor to control the device where the processor is located to implement the steps of the method for fine characterization of reservoir planar distribution characteristics described in the first aspect of the present invention.

[0043] In a fourth aspect, the present invention provides a computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the method for finely characterizing the planar distribution characteristics of the reservoir as described in the first aspect of the present invention when executing the computer program.

[0044] The present invention has the following advantages due to the adoption of the above technical solution:

[0045] The present invention discloses a method for finely characterizing the planar distribution characteristics of reservoirs based on topography control. The method uses three-dimensional seismic data and combines well and seismic data to track and interpret the top and bottom interfaces of the reservoir, obtain the paleo-geomorphology and present-day topography of the target layer, and combine the thickness of the actual drilled sand body to obtain the initial reservoir-sensitive seismic attributes. Based on the paleo-geomorphology and present-day topography, the initial reservoir-sensitive seismic attributes are corrected, and combined with actual drilling and logging information, the reservoir is finely characterized, thereby guiding the deployment and optimization of development well patterns, providing important technical support for the efficient development of underground oil and gas reservoirs and the adjustment of plans. In addition, it has the following advantages:

[0046] (1) The paleo-geomorphological correction method for the sensitive seismic attributes of the target reservoir is used to eliminate the reservoir response error information caused by strong basement reflection at the edge of the overlying sedimentary body, thereby improving the accuracy of reservoir characterization.

[0047] (2) The current method of terrain correction of the sensitive seismic attributes of the target reservoir is used to eliminate the phenomenon that the strong reflection of the gas-bearing reservoir leads to unclear internal characteristics of the target reservoir, effectively reducing the uncertainty of reservoir characterization. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] Various other advantages and benefits will become apparent to those skilled in the art upon reading the detailed description of the preferred embodiment below. The accompanying drawings are for illustration purposes only and are not to be considered as limiting the present invention. Throughout the drawings, the same reference numerals are used to denote the same components. In the drawings:

[0049] Figure 1 A schematic flow chart of a method for finely depicting reservoir planar distribution characteristics based on topography control provided by one embodiment of the present invention;

[0050] Figure 2 A schematic diagram of the top and bottom interfaces of the target reservoir interpreted by seismic tracing according to the present invention;

[0051] Figure 3a plan view of initial reservoir-sensitive seismic attributes obtained for the present invention;

[0052] Figure 4 A plan view of the target reservoir sedimentary paleo-geomorphology obtained for the present invention;

[0053] Figure 5 A plan view of the present topography of the target reservoir obtained for the present invention;

[0054] Figure 6 A plan view of sensitive seismic attributes of the target reservoir obtained by the present invention after correction for paleogeomorphic constraints;

[0055] Figure 7 A plan view of the sensitive seismic attributes of the target reservoir before and after correction of the current topographically constrained gas-bearing zone obtained by the present invention;

[0056] Figure 8 a plan view of the final reservoir-sensitive seismic attributes obtained for the present invention;

[0057] Figure 9 This is a plan view of the fine sedimentary facies of the target reservoir obtained for the present invention. DETAILED DESCRIPTION

[0058] To make the objectives, technical solutions, and advantages of the present invention more clear, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the embodiments described are only some of the embodiments of the present invention, not all of them. All other embodiments derived by persons of ordinary skill in the art based on the embodiments of the present invention without inventive effort are within the scope of protection of the present invention.

[0059] The present invention provides a method for finely characterizing reservoir planar distribution characteristics based on topography, including: conducting fine well-seismic calibration based on three-dimensional seismic data and combining well and seismic data, and tracking and interpreting the top and bottom interfaces of the target reservoir; obtaining initial reservoir-sensitive seismic attributes; obtaining the target reservoir sedimentary paleogeomorphology; obtaining the target reservoir's present-day topography based on the time-depth relationship of the fine well-seismic calibration; correcting the initial reservoir-sensitive seismic attributes based on the target reservoir sedimentary paleogeomorphology and the target reservoir's present-day topography to obtain the final target reservoir-sensitive seismic attributes, and compiling a target reservoir sedimentary facies map based on the final target reservoir-sensitive seismic attributes. The present invention addresses the uncertainty in reservoir characteristic analysis caused by strong reflections from basement and gas-bearing reservoirs by using paleogeomorphology and present-day topography to correct reservoir-sensitive seismic attributes, eliminating reservoir response errors caused by strong reflections from basement and gas-bearing reservoirs, improving the accuracy of reservoir characterization, and effectively reducing the uncertainty of reservoir analysis.

[0060] The method and apparatus for finely depicting reservoir planar distribution characteristics based on landform control provided by an embodiment of the present invention will be described in detail below with reference to the accompanying drawings.

[0061] Example 1:

[0062] See also Figure 1 This embodiment provides a method for finely characterizing reservoir planar distribution characteristics based on landform control, comprising the following steps:

[0063] S100. Based on 3D seismic data, carry out fine well-seismic calibration and trace and interpret the top and bottom interfaces of the target reservoir (see Figure 2 ); wherein, 3D seismic data includes geological data, seismic data and well logging data.

[0064] S200. Obtaining initial reservoir sensitive seismic attributes based on 3D seismic data and the top and bottom interfaces of the target reservoir. The specific steps are as follows:

[0065] S201. Using the top and bottom interfaces of the target reservoir as seismic time windows, extract seismic attributes representing the target reservoir based on 3D seismic data;

[0066] S202. Using the top and bottom interfaces of the target reservoir as constraints, calculate the actual drilling sand body thickness of the target reservoir;

[0067] S203. Perform correlation analysis on the extracted target reservoir seismic attributes and the target reservoir sand body thickness, and preferably obtain initial reservoir sensitive seismic attributes;

[0068] Depend on Figure 3 It can be seen that the target reservoir is distributed in a northeast-southwest direction and is mainly distributed in the central and western parts of the study area. Among them, the reservoir in the west is more developed. The reservoir in the east is affected by the strong reflection of the basement and cannot reflect the true reservoir characteristics.

[0069] S300. Obtaining target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir, the specific steps are:

[0070] S301. Taking the top and bottom interfaces of the target reservoir as constraints, obtain the primary paleo-geomorphology of the target reservoir by calculating the difference between the top and bottom interfaces of the target reservoir;

[0071] S302. Based on the obtained target reservoir primary paleo-geomorphology, obtain the target reservoir paleo-geomorphology after removing the fault influence by removing outliers and constraining geological knowledge;

[0072] S303. Based on the obtained target reservoir paleo-geomorphology after removing the influence of the fault, obtain the paleo-geomorphology after compaction correction as the target reservoir sedimentary paleo-geomorphology.

[0073] Depend on Figure 4 It can be seen that the paleo-geomorphology before the deposition of the target reservoir was generally low in the west and high in the east, and the thickness of the strata gradually decreased from west to east.

[0074] S400. Based on the top and bottom interfaces of the target reservoir and the time-depth relationship of fine well-seismic calibration, the current topography of the target reservoir is obtained. The specific steps are as follows:

[0075] S401. Taking the target reservoir top interface as a constraint, obtain the time domain structural data of the target reservoir top interface;

[0076] S402. Based on the time-depth relationship obtained by fine well-seismic calibration in step S100, a multi-well time-depth fitting method is used to obtain the time-depth relationship of the structural surface in the time domain and the structural surface in the depth domain;

[0077] S403. Based on the acquired time domain structural data of the target reservoir top interface and the time-depth relationship of the time domain structural surface and the depth domain structural surface conversion, obtain the target reservoir top interface structural data as the target reservoir current topography;

[0078] Depend on Figure 5 It can be seen that the overall topography of the target reservoir is characterized by high in the west and low in the east, and the structure gradually decreases from west to east.

[0079] S500. Based on the target reservoir sedimentary paleogeomorphology and the target reservoir present-day topography, correct the initial reservoir sensitive seismic attributes to obtain the final target reservoir sensitive seismic attributes, and compile the target reservoir sedimentary facies map based on the final target reservoir sensitive seismic attributes. The specific steps are as follows:

[0080] S501. Normalize the target reservoir sedimentary paleo-geomorphology obtained in step S303 to obtain paleo-geomorphology correction factors of the initial reservoir sensitive seismic attributes;

[0081] S502. Multiply the initial reservoir sensitive seismic attributes obtained in step S203 and the paleo-geomorphology correction factor obtained in step S501 to obtain the target reservoir sensitive seismic attributes after paleo-geomorphology constraint correction;

[0082] Depend on Figure 6 It can be seen that the sensitive seismic attributes of the target reservoir after paleo-geomorphic constraint correction eliminate the reservoir response error information caused by strong basement reflection at the edge of the overlying sedimentary body, thereby improving the accuracy of reservoir characterization.

[0083] S503. Based on the current topography of the target reservoir obtained in step S403 and the actual drilling gas layer depth, the gas-bearing boundary is obtained, and the sensitive seismic attributes of the target reservoir within the gas-bearing influence range are delineated accordingly; wherein the actual drilling gas layer depth is obtained based on the well logging interpretation results;

[0084] S504. Based on actual drilling fluid data and combined with forward model analysis, obtain a gas reservoir correction factor for the sensitive seismic attributes of the target reservoir; wherein the actual drilling fluid data is obtained based on well logging data (sonic wave curves, density curves), including velocity and density characteristics of gas, oil, and water reservoirs;

[0085] S505. Multiply the obtained sensitive seismic attributes of the target reservoir within the gas-bearing influence range by the gas-bearing reservoir correction factor to obtain the sensitive seismic attributes of the target reservoir after correction for the current terrain constraint;

[0086] Depend on Figure 7 It can be seen that the sensitive seismic attributes of the target reservoir after the current terrain constraint correction eliminate the phenomenon that the strong reflection of the gas-bearing reservoir leads to unclear internal characteristics of the reservoir. The internal characteristics of the reservoir within the gas-bearing range are clear, which effectively reduces the uncertainty of reservoir characterization.

[0087] S506. Fusing the sensitive seismic attributes of the target reservoir corrected for paleo-geomorphic constraints with the sensitive seismic attributes of the target reservoir corrected for current topography constraints to obtain the final sensitive seismic attributes of the target reservoir;

[0088] Depend on Figure 8 It can be seen that the target reservoir is distributed in a northeast-southwest direction as a whole. The reservoir is relatively developed near the main fault area on the west side, which is the main reservoir development area. Affected by the paleo-geomorphology gradually becoming higher to the east, the reservoir gradually becomes worse to the east.

[0089] S507. Based on the acquired sensitive seismic attributes of the final target reservoir and combined with the sedimentary facies knowledge obtained from actual drilling, compile a sedimentary facies map of the target reservoir.

[0090] Depend on Figure 9 It can be seen that the sedimentary facies diagram of the target reservoir is distributed in a northeast-southwest direction as a whole, consisting of two delta lobes, and three subfacies, namely fan root, fan middle and fan edge, are developed from west to east.

[0091] Example 2:

[0092] The above-mentioned embodiment 1 provides a method for fine characterization of reservoir plane distribution characteristics based on landform control. Correspondingly, this embodiment provides a device for fine characterization of reservoir plane distribution characteristics based on landform control. The device for fine characterization of reservoir plane distribution characteristics provided in this embodiment can implement the method for fine characterization of reservoir plane distribution characteristics of embodiment 1. The device for fine characterization of reservoir plane distribution characteristics can be implemented by software, hardware, or a combination of software and hardware. For example, the device for fine characterization of reservoir plane distribution characteristics can include integrated or separate functional modules or functional units to execute the corresponding steps in each method of embodiment 1. Since the device for fine characterization of reservoir plane distribution characteristics of this embodiment is basically similar to the method embodiment, the process described in this embodiment is relatively simple. For relevant matters, please refer to the partial description of embodiment 1. The device for fine characterization of reservoir plane distribution characteristics of this embodiment is merely schematic.

[0093] The device for finely depicting reservoir planar distribution characteristics provided in this embodiment includes:

[0094] The first processing unit is used to carry out fine well-seismic calibration based on 3D seismic data and the combination of well and seismic data, and to track and interpret the top and bottom interfaces of the target reservoir;

[0095] The second processing unit is used to obtain initial reservoir sensitive seismic attributes based on the three-dimensional seismic data and the top and bottom interfaces of the target reservoir;

[0096] The third processing unit is used to obtain the target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir;

[0097] The fourth processing unit is used to obtain the current topography of the target reservoir based on the top and bottom interfaces of the target reservoir and the time-depth relationship of the fine well-seismic calibration;

[0098] The fifth processing unit is used to correct the initial reservoir sensitive seismic attributes according to the target reservoir sedimentary paleo-geomorphology and the target reservoir current topography to obtain the final target reservoir sensitive seismic attributes, and compile the target reservoir sedimentary facies map according to the final target reservoir sensitive seismic attributes.

[0099] Example 3:

[0100] This embodiment provides a processing device for implementing the method for fine characterization of reservoir planar distribution characteristics based on topography control provided in this embodiment 1. The processing device can be a processing device for a client, such as a mobile phone, laptop computer, tablet computer, desktop computer, etc., to execute the method of embodiment 1.

[0101] The processing device includes a processor, a memory, a communication interface, and a bus. The processor, memory, and communication interface are connected via the bus to facilitate communication between them. The memory stores a computer program executable by the processor. When the processor executes the computer program, it executes the method for finely characterizing reservoir planar distribution features provided in Example 1.

[0102] Preferably, the memory may be a high-speed random access memory (RAM), and may also include a non-volatile memory, such as at least one disk memory.

[0103] Preferably, the processor may be a central processing unit (CPU), a digital signal processor (DSP), or other general-purpose processors of various types, which are not limited here.

[0104] Example 4:

[0105] The method for fine characterization of reservoir planar distribution characteristics based on topographic control in this embodiment 1 can be specifically implemented as a computer program product. The computer program product may include a computer-readable storage medium carrying computer-readable program instructions for executing the method described in this embodiment 1.

[0106] Computer readable storage media can be tangible devices that hold and store instructions used by instruction execution devices. Computer readable storage media can be, for example, but not limited to, electronic storage devices, magnetic storage devices, optical storage devices, electromagnetic storage devices, semiconductor storage devices, or any combination thereof.

[0107] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit them. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some or all of the technical features therein. These modifications or replacements do not deviate the essence of the corresponding technical solutions from the scope of the technical solutions of the embodiments of the present application, and they should all be included in the scope of the claims and specification of the present application. In particular, as long as there is no structural conflict, the various technical features mentioned in the various embodiments can be combined in any way. The present application is not limited to the specific embodiments disclosed herein, but includes all technical solutions that fall within the scope of the claims.

Claims

1. A method for finely depicting reservoir planar distribution characteristics based on landform control, characterized in that: The following steps are involved: Based on 3D seismic data, well-seismic analysis is combined to conduct fine well-seismic calibration and track and interpret the top and bottom interfaces of the target reservoir; Based on 3D seismic data and the top and bottom interfaces of the target reservoir, the initial reservoir sensitive seismic attributes are obtained; Obtain target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir; Based on the top and bottom interfaces of the target reservoir and the time-depth relationship of fine well-seismic calibration, the current topography of the target reservoir is obtained; According to the target reservoir sedimentary paleogeomorphology and the target reservoir present topography, the initial reservoir sensitive seismic attributes are corrected to obtain the final target reservoir sensitive seismic attributes, and the target reservoir sedimentary facies map is compiled based on the final target reservoir sensitive seismic attributes.

2. The method for finely depicting reservoir plane distribution characteristics according to claim 1, characterized in that: The three-dimensional seismic data includes geological data, seismic data and well logging data.

3. The method for finely depicting reservoir plane distribution characteristics according to claim 1, characterized in that: The aforementioned "obtaining initial reservoir sensitive seismic attributes based on 3D seismic data and the top and bottom interfaces of the target reservoir" is specifically: Taking the top and bottom interfaces of the target reservoir as seismic time windows, the seismic attributes of the target reservoir are extracted based on 3D seismic data; Taking the top and bottom interfaces of the target reservoir as constraints, calculate the actual drilling sand body thickness of the target reservoir; A correlation analysis is performed on the extracted target reservoir seismic attributes and the actual drilling sand body thickness of the target reservoir to obtain the initial reservoir sensitive seismic attributes.

4. The method for finely depicting reservoir plane distribution characteristics according to claim 3, characterized in that: The aforementioned "obtaining target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir" is specifically: Taking the top and bottom interfaces of the target reservoir as constraints, the primary paleo-geomorphology of the target reservoir is obtained by calculating the difference between the top and bottom interfaces of the target reservoir; Based on the acquired primary paleo-geomorphology of the target reservoir, the paleo-geomorphology of the target reservoir after removing the influence of faults is obtained by removing outliers and constraining geological knowledge; Based on the obtained target reservoir paleo-geomorphology after removing the influence of faults, the compaction-corrected paleo-geomorphology is obtained as the target reservoir sedimentary paleo-geomorphology.

5. The method for finely depicting reservoir plane distribution characteristics according to claim 4, characterized in that: The specific purpose of "obtaining the current topography of the target reservoir based on the top and bottom interfaces of the target reservoir and the time-depth relationship based on fine well-seismic calibration" is: Taking the top interface of the target reservoir as a constraint, obtain the time domain structural data of the top interface of the target reservoir; Based on the time-depth relationship obtained from fine well-seismic calibration, a multi-well time-depth fitting method is used to obtain the time-depth relationship of the structural surface in the time domain and the structural surface in the depth domain. Based on the acquired time-domain structural data of the top interface of the target reservoir and the time-depth relationship between the conversion of the time-domain structural surface and the depth-domain structural surface, the structural data of the top interface of the target reservoir are obtained as the current topography of the target reservoir.

6. The method for finely depicting reservoir plane distribution characteristics according to claim 5, characterized in that: The aforementioned "correcting the initial reservoir sensitive seismic attributes based on the target reservoir sedimentary paleogeomorphology and the target reservoir present-day topography to obtain the final target reservoir sensitive seismic attributes, and compiling the target reservoir sedimentary facies map based on the final target reservoir sensitive seismic attributes" specifically includes: Normalize the acquired target reservoir sedimentary paleogeomorphology to obtain the paleogeomorphological correction factor of the initial reservoir sensitive seismic attributes; Multiplying the initial reservoir sensitive seismic attributes and the paleo-geomorphology correction factor to obtain the target reservoir sensitive seismic attributes after paleo-geomorphology constraint correction; Based on the acquired current topography of the target reservoir and the actual drilling gas layer depth, the gas-bearing boundary is obtained, and the sensitive seismic attributes of the target reservoir within the gas-bearing influence range are delineated accordingly; the actual drilling gas layer depth is obtained based on the well logging interpretation results; Based on actual drilling fluid data and combined with forward model analysis, the gas reservoir correction factor of the sensitive seismic attributes of the target reservoir is obtained; Multiply the obtained sensitive seismic attributes of the target reservoir within the gas-bearing influence range by the gas-bearing reservoir correction factor to obtain the sensitive seismic attributes of the target reservoir after correction for the current terrain constraints; The sensitive seismic attributes of the target reservoir corrected by paleo-geomorphic constraints are merged with the sensitive seismic attributes of the target reservoir corrected by current topography constraints to obtain the final sensitive seismic attributes of the target reservoir; Based on the obtained sensitive seismic attributes of the final target reservoir and combined with the sedimentary facies knowledge from actual drilling, a sedimentary facies map of the target reservoir is compiled.

7. A device for finely depicting reservoir plane distribution characteristics based on landform control, characterized in that: include: The first processing unit is used to carry out fine well-seismic calibration based on 3D seismic data and the combination of well and seismic data, and to track and interpret the top and bottom interfaces of the target reservoir; The second processing unit is used to obtain initial reservoir sensitive seismic attributes based on the three-dimensional seismic data and the top and bottom interfaces of the target reservoir; The third processing unit is used to obtain the target reservoir sedimentary paleo-geomorphology based on the top and bottom interfaces of the target reservoir; The fourth processing unit is used to obtain the current topography of the target reservoir based on the top and bottom interfaces of the target reservoir and the time-depth relationship of the fine well-seismic calibration; The fifth processing unit is used to correct the initial reservoir sensitive seismic attributes according to the target reservoir sedimentary paleo-geomorphology and the target reservoir current topography to obtain the final target reservoir sensitive seismic attributes, and compile the target reservoir sedimentary facies map according to the final target reservoir sensitive seismic attributes.

8. A computer-readable storage medium, characterized in that A computer program is stored, and the computer program is executed by a processor to control the device where the processor is located to implement the steps of the method for fine characterization of reservoir planar distribution characteristics according to any one of claims 1 to 6.

9. A computer device, characterized in that: The method comprises a memory, a processor and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the method for finely characterizing the planar distribution characteristics of a reservoir according to any one of claims 1 to 6 when executing the computer program.

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