A method, apparatus, equipment, and storage medium for determining the bottom limit of nonconformity surface control storage.

Abstract

This invention discloses a method, apparatus, equipment, and storage medium for determining the reservoir control limit of an unconformity. The method includes: acquiring the reservoir geological characteristics of the target area and determining the stratigraphic position of the unconformity based on these characteristics; determining the vertical distance from the oil and gas producing interval of a single well to the unconformity based on drilling data, logging data, and single-well drilling and completion data associated with the stratigraphic position of the unconformity; determining the correlation between the vertical distance and oil and gas reservoir occurrence status assessment indicators matching various karst zone types; and determining the reservoir control limit of the target area based on the correlation. This technical solution solves the problem of low reliability in determining the reservoir control limit of carbonate unconformities, and can improve the accuracy of unconformity reservoir control limit prediction while providing corresponding technical support for the efficient exploration and development and potential zone selection of carbonate reservoirs.

Description

Technical Field

[0001] This invention relates to the field of reservoir development technology, and in particular to a method, apparatus, electronic device, and storage medium for determining the reservoir control limit of an unconformity surface. Background Technology

[0002] Carbonate rocks contain abundant oil and gas resources. Faults and unconformities are important channels for oil and gas migration. The lateral migration range of oil and gas along unconformities has a significant impact on the vertical accumulation height of oil and gas. For karst zones with different reservoir geological characteristics, the lower limit of unconformity control over oil and gas reservoir migration varies significantly, severely restricting the efficient exploration and development of this type of reservoir. Therefore, the study of the lower limit of unconformity control over reservoirs in carbonate rocks is particularly important.

[0003] Currently, the main research approach for determining the reservoir development scale controlled by unconformities in carbonate rocks involves identifying the primary controlling factors of reservoir genesis in karst zones through data from field outcrops, single-well core drilling, regional geological background, and diagenesis. For studies on reservoir control limits, a relatively systematic geochemical analysis of source rocks and hydrocarbon samples is typically conducted, combined with a systematic analysis of burial history, thermal evolution history, and fluid activity history to determine the reservoir control limit of the unconformity.

[0004] However, for ultra-deep reservoirs, where single wells have not encountered source rocks, research findings based on data from other regions have limitations and cannot meet the needs of efficient exploration and development of this type of oil and gas reservoir. Therefore, how to reliably determine the reservoir control limit of carbonate unconformities, which can provide technical support for efficient exploration and development and potential zone selection of carbonate reservoirs, has become an urgent problem to be solved by those skilled in the art. Summary of the Invention

[0005] This invention provides a method, apparatus, equipment, and storage medium for determining the limit of unconformity-controlled reservoirs in carbonate rocks, thereby solving the problem of low reliability in determining the limit of unconformity-controlled reservoirs in carbonate rocks. It can improve the accuracy of predicting the limit of unconformity-controlled reservoirs and provide corresponding technical support for the efficient exploration and development of carbonate oil reservoirs and the selection of potential zones.

[0006] According to one aspect of the present invention, a method for determining the bottom limit of nonconformity surface control is provided, the method comprising:

[0007] Obtain the reservoir geological characteristics of the target area, and determine the stratigraphic position of the unconformity surface based on the reservoir geological characteristics;

[0008] Based on the drilling data, logging data and single-well drilling and completion data of the unconformity, determine the vertical distance from the oil and gas producing interval of a single well to the unconformity.

[0009] The correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators matching each karst area type is determined; wherein, the oil and gas reservoir occurrence status assessment indicators matching each karst area type are determined in advance based on the detection data of stratigraphic correlation of unconformity surfaces.

[0010] Based on the aforementioned correlation, the unconformity control limit of the target area is determined.

[0011] According to another aspect of the present invention, a non-integral surface control limit determination device is provided, the device comprising:

[0012] The stratigraphic determination module is used to acquire the reservoir geological characteristics of the target area and determine the stratigraphic position of the unconformity surface based on the reservoir geological characteristics.

[0013] The vertical distance determination module is used to determine the vertical distance from the oil and gas producing section of a single well to the unconformity surface based on the drilling data, logging data and single well drilling and completion data associated with the unconformity surface.

[0014] The correlation determination module is used to determine the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators that match each karst area type; wherein, the oil and gas reservoir occurrence status assessment indicators that match each karst area type are determined in advance based on the detection data of stratigraphic correlation of unconformity surfaces.

[0015] The control limit determination module is used to determine the non-conformity control limit of the target area based on the aforementioned correlation.

[0016] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0017] At least one processor; and

[0018] A memory communicatively connected to the at least one processor; wherein,

[0019] 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 non-integral surface control limit determination method according to any embodiment of the present invention.

[0020] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the non-integrated surface control limit determination method according to any embodiment of the present invention.

[0021] The technical solution of this invention involves acquiring the reservoir geological characteristics of the target area, determining the stratigraphic position of the unconformity surface based on these characteristics, then determining the vertical distance from the oil and gas producing interval of a single well to the unconformity surface based on the drilling data, logging data, and single-well drilling and completion data associated with the unconformity surface stratigraphic position; further, determining the correlation between the vertical distance and oil and gas reservoir occurrence status assessment indicators matching each karst type; and finally, determining the reservoir control limit of the unconformity surface in the target area based on the aforementioned correlation. This technical solution solves the problem of low reliability in determining the reservoir control limit of carbonate rock unconformities, and can improve the accuracy of predicting the reservoir control limit of unconformities while providing corresponding technical support for the efficient exploration and development of carbonate reservoirs and the selection of potential zones.

[0022] 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

[0023] 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.

[0024] Figure 1 This is a flowchart of a method for determining the bottom limit of non-integral surface control according to Embodiment 1 of the present invention;

[0025] Figure 2A This is a flowchart of a method for determining the bottom limit of non-integral surface control according to Embodiment 2 of the present invention;

[0026] Figure 2B This is a seismic profile of the X oilfield provided in Embodiment 2 of the present invention;

[0027] Figure 2C This is a schematic diagram of the intersection analysis of the daily oil production and vertical distance of each single well in the interlayer karst zone according to Embodiment 2 of the present invention;

[0028] Figure 2D This is a schematic diagram of the intersection analysis of daily oil production and vertical distance in the interlayer karst zone matching according to Embodiment 2 of the present invention;

[0029] Figure 3 This is a schematic diagram of a non-integral surface control storage limit determination device according to Embodiment 3 of the present invention;

[0030] Figure 4This is a schematic diagram of the structure of an electronic device that implements the method for determining the bottom limit of non-integrated surface control according to an embodiment of the present invention. Detailed Implementation

[0031] 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.

[0032] It should be noted that the terms "first," "second," 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 used interchangeably where appropriate so that the 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 non-exclusive inclusion; for example, a process, method, system, product, or device 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 devices. The acquisition, storage, use, and processing of data in the technical solutions of this application all comply with the relevant provisions of national laws and regulations.

[0033] Example 1

[0034] Figure 1 This document provides a flowchart of a method for determining the bottom limit of non-integral surface-controlled hideouts according to Embodiment 1 of the present invention. This embodiment is applicable to scenarios involving the prediction of the bottom limit of non-integral surface-controlled hideouts. This method can be executed by a device for determining the bottom limit of non-integral surface-controlled hideouts. This device can be implemented in hardware and / or software and can be configured in an electronic device. Figure 1 As shown, the method includes:

[0035] S110. Obtain the reservoir geological characteristics of the target area and determine the stratigraphic position of the unconformity based on the reservoir geological characteristics.

[0036] This scheme utilizes geological and seismic data from the target area to determine the reservoir's geological characteristics. Specifically, based on the reservoir's geological background, it identifies the unconformity stratigraphic levels within the developed reservoir area. By interpreting and analyzing the seismic data of the target area, the stratigraphic levels of the unconformity surfaces throughout the entire target area can be determined based on the unconformity stratigraphic levels within the developed reservoir area.

[0037] S120. Based on the drilling data, logging data, and single-well drilling and completion data related to the stratigraphic relationship of the unconformity, determine the vertical distance from the oil and gas producing section of a single well to the unconformity.

[0038] After determining the stratigraphic position of the unconformity, drilling, logging, and well completion data for the area containing the unconformity are acquired. Based on the drilling, logging, and well completion data associated with the unconformity stratigraphic position, the vertical distance from the oil-bearing zone to the unconformity can be calculated. Specifically, based on the drilling and logging data, by identifying typical sedimentary backgrounds and cuttings characteristics, the lateral and vertical depths of the unconformity actually encountered by the well can be determined. Based on the well completion data, the lateral and vertical depths of the bottom of the oil-bearing layer actually encountered by the well can be determined. Based on the vertical depths of the unconformity and the bottom of the oil-bearing layer actually encountered by the well, the vertical distance from the oil-bearing zone to the unconformity can be determined. It can be understood that the difference between the vertical depth of the unconformity and the vertical depth of the bottom of the oil-bearing layer actually encountered by the well is the vertical distance from the oil-bearing zone to the unconformity.

[0039] In a preferred embodiment, the testing interval for a single well can be determined based on the single-well testing data, and the lateral and vertical depths of the bottom of the testing interval can be statistically analyzed. By comparing and analyzing the bottom depth of the completed well and the depth of the bottom of the testing interval, for wells with both parameters available, the bottom data of the testing interval can be selected as the bottom of the oil-producing interval. For wells without testing interval data, the bottom of the completed well can be selected as the bottom of the oil-producing interval.

[0040] S130. Determine the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators that match each karst zone type.

[0041] The oil and gas reservoir occurrence status assessment indicators matched to each karst region type are determined in advance based on stratigraphic correlation data of the unconformity surface. The detection data may include oil and gas testing data, fluid property detection data, and drilling gas logging anomaly data. Based on the detection data of each individual well, the oil and gas reservoir occurrence status assessment indicators for each well can be determined, and then, based on the karst region type to which each well belongs, the oil and gas reservoir occurrence status assessment indicators matched to each karst region type can be determined. The karst region types may include buried hill karst regions, inter-layer karst regions, and fault-controlled karst regions. The oil and gas reservoir occurrence status assessment indicators may include indicators such as the actual oil and gas production of the target layer encountered by the well, the percentage of cumulative oil production to cumulative oil and gas equivalent production in each stage, total hydrocarbon content, C1 content, and C2+ content.

[0042] After determining the oil and gas reservoir occurrence status assessment indicators that match each karst area type, the vertical distance was intersected with the oil and gas reservoir occurrence status assessment indicators that match each karst area type to obtain the correlation between the vertical distance and the oil and gas reservoir occurrence status assessment indicators that match each karst area type.

[0043] S140. Based on the aforementioned correlation, determine the unconformity control limit of the target area.

[0044] After obtaining the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators that match each karst zone type, the vertical distance from the oil and gas producing interval of a single well to the unconformity surface can be determined based on the known karst zone type of a single well and at least one oil and gas reservoir occurrence status assessment indicator, thereby obtaining the unconformity surface control limit of the target area.

[0045] The technical solution of this invention involves acquiring the reservoir geological characteristics of the target area, determining the stratigraphic position of the unconformity surface based on these characteristics, then determining the vertical distance from the oil and gas producing interval of a single well to the unconformity surface based on the drilling data, logging data, and single-well drilling and completion data associated with the unconformity surface stratigraphic position; further, determining the correlation between the vertical distance and oil and gas reservoir occurrence status assessment indicators matching each karst type; and finally, determining the reservoir control limit of the unconformity surface in the target area based on the aforementioned correlation. This technical solution solves the problem of low reliability in determining the reservoir control limit of carbonate rock unconformities, and can improve the accuracy of predicting the reservoir control limit of unconformities while providing corresponding technical support for the efficient exploration and development of carbonate reservoirs and the selection of potential zones.

[0046] Example 2

[0047] Figure 2A This is a flowchart of a method for determining the bottom limit of non-integral surface control storage provided in Embodiment 2 of the present invention. This embodiment is a refinement based on the above embodiment. Figure 2A As shown, the method includes:

[0048] S210. Obtain the reservoir geological characteristics of the target area and determine the stratigraphic position of the unconformity based on the reservoir geological characteristics.

[0049] This plan uses the X oilfield as an example to illustrate the process of determining the bottom limit of unconformity surface reservoirs. Figure 2B This is a seismic profile of the X oilfield provided according to Embodiment 2 of the present invention, such as... Figure 2B As shown, the Ordovician Yifang Formation in the carbonate reservoir of the X oilfield is a set of parallel unconformities in the region.

[0050] S220. Determine the depth of the unconformity encountered in a single well based on the drilling data and logging data related to the stratigraphic relationship of the unconformity.

[0051] S230. Based on the single-well drilling and completion data related to the stratigraphic relationship of the unconformity surface, determine the bottom depth of the single-well oil testing and production test.

[0052] The depths of unconformities encountered by single wells and the depths of oil-testing zones after drilling in the X oilfield are shown in Table 1 below.

[0053] Table 1:

[0054]

[0055] S240. Based on the depth of the unconformity encountered in a single well and the bottom depth of the single well test well, determine the vertical distance from the oil and gas producing section of the single well to the unconformity.

[0056] As shown in Table 1, the vertical distance from the oil and gas producing section of a single well to the unconformity can be calculated based on the depth of the unconformity encountered during drilling and the depth of the oil-bearing test section after drilling. This distance is the distance from the unconformity in Table 1.

[0057] S250. Determine the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators that match each karst zone type.

[0058] In this scheme, optionally, the process for determining the assessment indicators of oil and gas reservoir occurrence status matching each karst area type includes:

[0059] Based on the detection data, the oil and gas reservoir occurrence status assessment indicators for a single well are determined; wherein, the detection data includes oil testing and production testing data and abnormal gas logging data while drilling;

[0060] Based on the single-well oil and gas reservoir occurrence status assessment index, determine the matching oil and gas reservoir occurrence status assessment index for each karst area type.

[0061] Understandably, the detection data can include oil and gas testing data and abnormal gas logging data during drilling. Based on these data, the reservoir occurrence status assessment indicators for a single well can be determined. According to the reservoir characteristics encountered by a single well, the type of karst region to which the well belongs can be determined in advance. Based on the karst region type and the reservoir occurrence status assessment indicators for a single well, the reservoir occurrence status assessment indicators for different karst region types can be statistically classified to obtain reservoir occurrence status assessment indicators matching each karst region type.

[0062] In a feasible scheme, determining the hydrocarbon reservoir occurrence status assessment indicators matching each karst zone type includes:

[0063] Based on the reservoir characteristics encountered by a single well, the type of karst zone to which the single well belongs is determined; among which, the types of karst zones include buried hill karst zones, interlayer karst zones, and fault-controlled karst zones;

[0064] Based on the assessment indicators of oil and gas reservoir occurrence status of a single well and the type of karst area to which the single well belongs, the assessment indicators of oil and gas reservoir occurrence status matching each type of karst area are determined.

[0065] Based on the above scheme, the oil and gas reservoir occurrence status assessment indicators include at least one of the following: oil production, gas production, cumulative oil production ratio, total hydrocarbon content, first carbon compound content, and second carbon compound content;

[0066] The determination of oil and gas reservoir occurrence status assessment indicators based on detection data includes:

[0067] Based on the oil and gas production test data, the oil production, gas production, and cumulative oil production ratio were determined. Based on the abnormal gas logging data while drilling, the total hydrocarbon content, first carbon compound content, and second carbon compound content were determined.

[0068] Table 2 shows the oil testing and production data of each well in the X oilfield, and Table 3 shows the abnormal gas logging data of each well in the X oilfield.

[0069] As is easily understood, the oil production may include the daily oil production converted from a single well test, the gas production may include the daily gas production converted from a single well test, the cumulative oil production ratio may include the percentage of cumulative oil production in a stage to the cumulative oil and gas equivalent in a stage, the first carbon compound content may include the C1 content of different target layers during the drilling process of a single well, and the second carbon compound content may include the C2+ content of different target layers during the drilling process of a single well.

[0070] Based on the oil testing and production data of each individual well, the daily oil production, daily gas production, and percentage of cumulative oil production to total cumulative oil and gas production can be determined. Based on the gas logging anomaly data of each individual well, the total hydrocarbon content, C1 content, and C2+ content of different target formations during drilling can be determined.

[0071] Table 2:

[0072]

[0073] Table 3:

[0074]

[0075] In a preferred embodiment, determining the oil and gas reservoir occurrence status assessment indicators matching each karst zone type based on the single well's oil and gas reservoir occurrence status assessment indicators and the karst zone type to which the single well belongs includes:

[0076] Based on the type of karst area to which the individual well belongs, determine the individual wells for each type of karst area;

[0077] Each karst region type is sequentially taken as the target karst region type. Based on the oil and gas reservoir occurrence status assessment index matched by each single well in the target karst region type and the measurement depth corresponding to the oil and gas reservoir occurrence status assessment index, the oil and gas reservoir occurrence status assessment index matched by the target karst region type is calculated.

[0078] After identifying individual wells for each karst region type, the reservoir occurrence status assessment indicators for each karst region type can be weighted by depth based on the distance from the unconformity surface. The specific calculation method for the reservoir occurrence status assessment indicators matching the target karst region type is as follows:

[0079] Where A represents the assessment index of the occurrence state of oil and gas reservoirs matching the target karst area type, A1, A2...A n The indicators representing the oil and gas reservoir occurrence status assessment indicators for each single well of the target karst area type are D1, D2…D n This indicates the measurement depth corresponding to the assessment index of the occurrence status of oil and gas reservoirs in each single well.

[0080] Table 4 shows the evaluation indicators of the oil and gas reservoir occurrence status of each single well in the X oilfield.

[0081] Table 4:

[0082]

[0083] Figure 2C This is a schematic diagram illustrating the intersection analysis of daily oil production and vertical distance of each single well in the interlayer karst zone according to Embodiment 2 of the present invention. Figure 2D This is a schematic diagram of the cross-analysis of daily oil production and vertical distance in interlayer karst zones according to Embodiment 2 of the present invention. Taking the correlation between the vertical distance and daily oil production in interlayer karst zones as an example, the daily oil production and vertical distance of each single well in the interlayer karst zone are directly cross-analyzed to obtain the following results: Figure 2C The scatter plot shown is based on Figure 2C The scatter distribution shown makes it difficult to fit the correlation between the daily oil production from the test wells and the vertical distance. After performing a depth-weighted average of the daily oil production from each single well within the interlayer karst zone, and then conducting a cross-analysis of the daily oil production from the test wells and the vertical distance within the interlayer karst zone, the correlation can be obtained. Figure 2D The diagram shows the relationship between the indicators and vertical distances of oil and gas reservoir occurrence status assessment, thus ensuring the feasibility of predicting the bottom limit of reservoir control on unconformities.

[0084] In this embodiment, determining the correlation between vertical distance and the oil and gas reservoir occurrence status assessment indicators matching each karst zone type includes:

[0085] If the number of oil and gas reservoir occurrence status assessment indicators matching the target karst area type is greater than 1, then the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type will be subjected to intersection analysis in turn to obtain the correlation between the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type.

[0086] It should be noted that the number of oil and gas reservoir occurrence status assessment indicators matching the target karst area type can be one or more. If there are multiple oil and gas reservoir occurrence status assessment indicators matching the target karst area type, then the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type are intersected and analyzed in turn. A correlation chart between vertical distance and each oil and gas reservoir occurrence status assessment indicator is plotted to obtain the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators matching the target karst area type.

[0087] S260. Based on the aforementioned correlation, determine the unconformity control limit of the target area.

[0088] The aforementioned scheme fully considers various dynamic and static data, including the geological background of the reservoir area, seismic inversion data, depth of unconformities encountered by wells, completion depth, bottom depth of test well sections, test production data, fluid analysis and testing data, and gas logging anomaly data. Based on fully utilizing the dynamic and static characteristics of actual development wells, it systematically analyzes the production characteristics of various wells controlled by unconformities, and uses this to predict trends, thereby obtaining the reservoir control limit of carbonate unconformities. Through the full integration of multiple disciplines and data, the research results are directly relevant to all completed and put into production wells, solving practical production problems of concern in the oilfield and providing important technical support for the efficient exploration and development of similar areas.

[0089] The technical solution of this invention involves acquiring the reservoir geological characteristics of the target area, determining the stratigraphic position of the unconformity surface based on these characteristics, then determining the vertical distance from the oil and gas producing interval of a single well to the unconformity surface based on the drilling data, logging data, and single-well drilling and completion data associated with the unconformity surface stratigraphic position; further, determining the correlation between the vertical distance and oil and gas reservoir occurrence status assessment indicators matching each karst type; and finally, determining the reservoir control limit of the unconformity surface in the target area based on the aforementioned correlation. This technical solution solves the problem of low reliability in determining the reservoir control limit of carbonate rock unconformities, and can improve the accuracy of predicting the reservoir control limit of unconformities while providing corresponding technical support for the efficient exploration and development of carbonate reservoirs and the selection of potential zones.

[0090] Example 3

[0091] Figure 3 This is a schematic diagram of a non-integral surface control storage limit determination device provided in Embodiment 3 of the present invention. Figure 3As shown, the device includes:

[0092] The stratigraphic determination module 310 is used to acquire the reservoir geological characteristics of the target area and determine the stratigraphic position of the unconformity surface based on the reservoir geological characteristics.

[0093] The vertical distance determination module 320 is used to determine the vertical distance from the oil and gas producing section of a single well to the unconformity surface based on the drilling data, logging data and single well drilling and completion data associated with the unconformity surface.

[0094] The correlation determination module 330 is used to determine the correlation between the vertical distance and the oil and gas reservoir occurrence status assessment index that matches each karst area type; wherein, the oil and gas reservoir occurrence status assessment index that matches each karst area type is determined in advance based on the detection data of stratigraphic correlation of unconformity surface.

[0095] The control limit determination module 340 is used to determine the unconformity control limit of the target area based on the association relationship.

[0096] In this solution, optionally, the vertical distance determination module 320 is specifically used for:

[0097] The depth of the unconformity encountered in a single well is determined based on the drilling data and logging data related to the stratigraphic relationship of the unconformity.

[0098] Based on the single-well drilling and completion data of the unconformity surface stratigraphic correlation, determine the bottom depth of the single-well oil testing and production test well;

[0099] Based on the depth of the unconformity encountered in a single well and the bottom depth of the single well test well, the vertical distance from the oil and gas producing section of a single well to the unconformity is determined.

[0100] In one feasible embodiment, the device further includes an index determination model, the index determination model comprising:

[0101] The single-well index determination unit is used to determine the oil and gas reservoir occurrence status assessment index of a single well based on the detection data; wherein, the detection data includes oil testing and production testing data and abnormal gas logging data while drilling;

[0102] The karst area type index determination unit is used to determine the oil and gas reservoir occurrence status assessment index that matches each karst area type based on the single well's oil and gas reservoir occurrence status assessment index.

[0103] Based on the above scheme, optionally, the oil and gas reservoir occurrence status assessment index includes at least one of oil production, gas production, cumulative oil production ratio, total hydrocarbon content, first carbon compound content, and second carbon compound content;

[0104] The single-well index determination unit is specifically used for:

[0105] Based on the oil and gas production test data, the oil production, gas production, and cumulative oil production ratio were determined. Based on the abnormal gas logging data while drilling, the total hydrocarbon content, first carbon compound content, and second carbon compound content were determined.

[0106] Optionally, the karst area type index determination unit includes:

[0107] The karst zone type determination subunit is used to determine the karst zone type of a single well based on the reservoir characteristics encountered during drilling; among which, the karst zone types include buried hill karst zones, interlayer karst zones, and fault-controlled karst zones;

[0108] The karst region type index determination subunit is used to determine the oil and gas reservoir occurrence status assessment index matching each karst region type based on the oil and gas reservoir occurrence status assessment index of a single well and the karst region type to which the single well belongs.

[0109] In a preferred embodiment, the karst zone type index determination sub-unit is specifically used for:

[0110] Based on the type of karst area to which the individual well belongs, determine the individual wells for each type of karst area;

[0111] Each karst region type is sequentially taken as the target karst region type. Based on the oil and gas reservoir occurrence status assessment index matched by each single well in the target karst region type and the measurement depth corresponding to the oil and gas reservoir occurrence status assessment index, the oil and gas reservoir occurrence status assessment index matched by the target karst region type is calculated.

[0112] Based on the above solution, optionally, the association determination module 330 is specifically used for:

[0113] If the number of oil and gas reservoir occurrence status assessment indicators matching the target karst area type is greater than 1, then the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type will be subjected to intersection analysis in turn to obtain the correlation between the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type.

[0114] The nonconformity surface control limit determination device provided in the embodiments of the present invention can execute the nonconformity surface control limit determination method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the method.

[0115] Example 4

[0116] Figure 4A schematic diagram of an electronic device 410 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 laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, 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.

[0117] like Figure 4 As shown, the electronic device 410 includes at least one processor 411 and a memory, such as a read-only memory (ROM) 412 or a random access memory (RAM) 413, communicatively connected to the at least one processor 411. The memory stores computer programs executable by the at least one processor. The processor 411 can perform various appropriate actions and processes based on the computer program stored in the ROM 412 or loaded from storage unit 418 into the RAM 413. The RAM 413 may also store various programs and data required for the operation of the electronic device 410. The processor 411, ROM 412, and RAM 413 are interconnected via a bus 414. An input / output (I / O) interface 415 is also connected to the bus 414.

[0118] Multiple components in electronic device 410 are connected to I / O interface 415, including: input unit 416, such as keyboard, mouse, etc.; output unit 417, such as various types of displays, speakers, etc.; storage unit 418, such as disk, optical disk, etc.; and communication unit 419, such as network card, modem, wireless transceiver, etc. Communication unit 419 allows electronic device 410 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0119] Processor 411 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 411 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 411 performs the various methods and processes described above, such as the method for determining the bottom limit of a non-integrated surface control.

[0120] In some embodiments, the non-integrated surface control limit determination method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 418. In some embodiments, part or all of the computer program may be loaded and / or installed on electronic device 410 via ROM 412 and / or communication unit 419. When the computer program is loaded into RAM 413 and executed by processor 411, one or more steps of the non-integrated surface control limit determination method described above may be performed. Alternatively, in other embodiments, processor 411 may be configured to perform the non-integrated surface control limit determination method by any other suitable means (e.g., by means of firmware).

[0121] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0122] Computer programs used to implement the methods of the present invention can be written in any combination of one or more programming languages. These computer programs can be provided to the processor of a general-purpose computer, a special-purpose computer, or other programmable non-integrated control limit determination device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be implemented. The computer programs can be executed entirely on a machine, partially on a machine, as a standalone software package partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0123] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0124] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0125] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0126] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0127] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0128] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for determining the bottom limit of unconformity surface control, characterized in that, The method includes: Obtain the reservoir geological characteristics of the target area, and determine the stratigraphic position of the unconformity based on the reservoir geological characteristics; Based on the drilling data, logging data and single-well drilling and completion data of the unconformity, determine the vertical distance from the oil and gas producing interval of a single well to the unconformity. The correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators matching each karst area type is determined; wherein, the oil and gas reservoir occurrence status assessment indicators matching each karst area type are determined in advance based on the detection data of stratigraphic correlation of unconformity surfaces. Based on the aforementioned correlation, the unconformity control limit of the target area is determined.

2. The method according to claim 1, characterized in that, The determination of the vertical distance from the oil and gas producing interval of a single well to the unconformity surface based on the drilling data, logging data, and single-well drilling and completion data associated with the unconformity surface includes: The depth of the unconformity encountered in a single well is determined based on the drilling data and logging data related to the stratigraphic relationship of the unconformity. Based on the single-well drilling and completion data associated with the unconformity surface, determine the bottom depth of the single-well oil testing and production test. Based on the depth of the unconformity encountered in a single well and the bottom depth of the single well test well, the vertical distance from the oil and gas producing section of a single well to the unconformity is determined.

3. The method according to claim 1, characterized in that, The process of determining the assessment indicators for the occurrence status of oil and gas reservoirs matching each karst region type includes: Based on the detection data, the oil and gas reservoir occurrence status assessment indicators for a single well are determined; wherein, the detection data includes oil testing and production testing data and abnormal gas logging data while drilling; Based on the single-well oil and gas reservoir occurrence status assessment index, determine the matching oil and gas reservoir occurrence status assessment index for each karst area type.

4. The method according to claim 3, characterized in that, The oil and gas reservoir occurrence status assessment indicators include oil production, gas production, cumulative oil production ratio, total hydrocarbon content, first carbon compound content, and second carbon compound content. The process of determining the oil and gas reservoir occurrence status assessment indicators for a single well based on the detection data includes: Based on the oil and gas production test data, the oil production, gas production, and cumulative oil production ratio of a single well are determined. Based on the abnormal gas logging data while drilling, the total hydrocarbon content, the content of first carbon compounds, and the content of second carbon compounds are determined.

5. The method according to claim 3, characterized in that, The process of determining oil and gas reservoir occurrence status assessment indicators matching each karst zone type based on single-well oil and gas reservoir occurrence status assessment indicators includes: Based on the reservoir characteristics encountered by a single well, the type of karst zone to which the single well belongs is determined; among them, the types of karst zones include buried hill karst zones, interlayer karst zones, and fault-controlled karst zones; Based on the assessment indicators of oil and gas reservoir occurrence status of a single well and the type of karst area to which the single well belongs, the assessment indicators of oil and gas reservoir occurrence status matching each type of karst area are determined.

6. The method according to claim 5, characterized in that, The process of determining oil and gas reservoir occurrence status assessment indicators for each karst region type based on the single well's oil and gas reservoir occurrence status assessment indicators and the karst region type to which the single well belongs includes: Based on the type of karst area to which the individual well belongs, determine the individual wells for each type of karst area; Each karst region type is sequentially taken as the target karst region type. Based on the oil and gas reservoir occurrence status assessment index matched by each single well in the target karst region type and the measurement depth corresponding to the oil and gas reservoir occurrence status assessment index, the oil and gas reservoir occurrence status assessment index matched by the target karst region type is calculated.

7. The method according to claim 6, characterized in that, The correlation between the vertical distance and the hydrocarbon reservoir occurrence status assessment indicators that match each karst zone type includes: If the number of oil and gas reservoir occurrence status assessment indicators matching the target karst area type is greater than 1, then the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type will be subjected to intersection analysis in turn to obtain the correlation between the vertical distance and each oil and gas reservoir occurrence status assessment indicator matching the target karst area type.

8. A device for determining the bottom limit of non-integral surface control, characterized in that, include: The stratigraphic determination module is used to acquire the reservoir geological characteristics of the target area and determine the stratigraphic position of the unconformity surface based on the reservoir geological characteristics. The vertical distance determination module is used to determine the vertical distance from the oil and gas producing section of a single well to the unconformity surface based on the drilling data, logging data and single well drilling and completion data associated with the unconformity surface. The correlation determination module is used to determine the correlation between vertical distance and oil and gas reservoir occurrence status assessment indicators that match each karst area type; The control limit determination module is used to determine the non-conformity control limit of the target area based on the aforementioned correlation.

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 executable by the at least one processor, which is executed by the at least one processor to enable the at least one processor to perform the method for determining the unintegrated surface control limit as described in any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the method for determining the unintegrated surface control limit as described in any one of claims 1-7.

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