Buried hill reservoir mining method, device, electronic equipment and storage medium

Abstract

The application provides a buried hill oil reservoir mining method and device, electronic equipment and a storage medium; applied to the field of oil and gas resource development, comprising: carrying out reservoir feature evaluation on a target buried hill oil reservoir to obtain a comprehensive evaluation result; based on the comprehensive evaluation result, configuring the structure of a three-dimensional well pattern corresponding to the target buried hill oil reservoir to obtain a target three-dimensional well pattern; the target three-dimensional well pattern is used for collecting the target buried hill oil reservoir; the three-dimensional well pattern comprises a gas injection well, an oil production well and a water injection well; the target three-dimensional well pattern is monitored in real time to obtain production data of the target three-dimensional well pattern, and based on the production data, injection and production parameters of each well are adjusted to obtain target injection and production parameters; based on the target injection and production parameters and the oil production process corresponding to each well, the target buried hill oil reservoir is mined by using the target three-dimensional well pattern. In this way, the oil reservoir recovery rate and oil production speed can be improved.

Description

Technical Field

[0001] This application relates to the field of oil and gas resource development, and in particular to a method, apparatus, electronic equipment and storage medium for the exploitation of buried hill oil reservoirs. Background Technology

[0002] Buried hill reservoirs are characterized by large reserves and wide distribution, and their scale and development technologies are of significant reference value for modern oil and gas exploration. Due to the complex structural traps, unique reservoir spaces, and extremely high heterogeneity, it is often difficult to comprehensively balance production rate and enhanced oil recovery when formulating development plans for such reservoirs. Primary, secondary, and even tertiary recovery processes are often difficult to implement in a timely manner, hindering the full development of the reservoir. This is particularly true for ancient buried hill reservoirs at sea, where current development methods cannot balance the two core indicators of production rate and enhanced oil recovery due to limitations in development conditions. Therefore, current buried hill reservoir development methods result in relatively low reservoir recovery rates and production rates. Summary of the Invention

[0003] This application provides a method, apparatus, electronic device, and storage medium for exploiting buried hill oil reservoirs to solve one or more problems existing in related technologies.

[0004] This application provides a method for exploiting buried hill reservoirs. The method includes: assessing the reservoir characteristics of a target buried hill reservoir to obtain a comprehensive assessment result; the comprehensive assessment result includes structural characteristic assessment results, reservoir heterogeneity assessment results, reservoir energy assessment results, and remaining oil distribution assessment results; configuring the structure of a three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive assessment result to obtain a target three-dimensional well network; the target three-dimensional well network is used to collect data from the target buried hill reservoir; the three-dimensional well network includes gas injection wells, oil production wells, and water injection wells; monitoring the target three-dimensional well network in real time to obtain production data of the target three-dimensional well network, and adjusting the injection and production parameters of each well based on the production data to obtain target injection and production parameters; and exploiting the target buried hill reservoir using the target three-dimensional well network based on the target injection and production parameters and the corresponding oil production technology of each well.

[0005] According to one embodiment of this application, the process of evaluating the reservoir characteristics of the target buried hill reservoir to obtain a comprehensive evaluation result includes: evaluating the structural characteristics of the target buried hill reservoir to obtain a structural characteristic evaluation result; the structural characteristic evaluation result includes structural morphology, fracture system, and buried hill amplitude; evaluating the reservoir heterogeneity of the target buried hill reservoir to obtain a reservoir heterogeneity evaluation result; the reservoir heterogeneity evaluation result includes macroscopic reservoir parameters and microscopic fluid parameters; evaluating the reservoir energy of the target buried hill reservoir to obtain a reservoir energy evaluation result; the reservoir energy evaluation result includes bottom water intensity and edge water intensity; and evaluating the remaining oil distribution of the target buried hill reservoir to obtain a remaining oil distribution evaluation result; the remaining oil distribution evaluation result includes remaining oil enrichment areas and remaining oil reserves.

[0006] According to one embodiment of this application, configuring the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation results to obtain the target three-dimensional well network includes: configuring the location and number of gas injection wells based on the structural feature evaluation results and the remaining oil distribution evaluation results to obtain target gas injection wells; configuring the vertical position of the wellbore perforations and the planar position of the production wells based on the reservoir energy evaluation results and the remaining oil distribution evaluation results to obtain target production wells; configuring the location and number of water injection wells based on the reservoir energy evaluation results and the reservoir heterogeneity evaluation results to obtain target water injection wells; and constructing the target three-dimensional well network based on the target gas injection wells, the target production wells, and the target water injection wells.

[0007] According to one embodiment of this application, the step of real-time monitoring of the target three-dimensional well network to obtain production data of the target three-dimensional well network, and adjusting the injection and production parameters of each well based on the production data to obtain target injection and production parameters, includes: the production data including pressure data, production data, water cut data, and gas cut data corresponding to the target three-dimensional well network; the target three-dimensional well network including target gas injection wells, target oil production wells, and target water injection wells; and dynamically adjusting the gas injection parameters of the target gas injection wells, the oil production parameters of the target oil production wells, and the water injection parameters of the target water injection wells based on the production data to obtain the target injection and production parameters.

[0008] According to one embodiment of this application, the oil production process includes: profile control and water shut-off process for the target gas injection well, lift process for the target oil production well, and water control measures for the target water injection well.

[0009] According to one embodiment of this application, the method further includes: in response to the reservoir energy assessment result including bottom water intensity being greater than a set first bottom water intensity threshold, configuring the vertical position at a first position at the oil column height corresponding to the oil well; in response to the reservoir energy assessment result including bottom water intensity being less than a set second bottom water intensity threshold, configuring the vertical position at a second position at the oil column height corresponding to the oil well; the first bottom water intensity threshold and the second bottom water intensity threshold are the same as or different; the first position is lower than the second position; in response to the reservoir energy assessment result including edge water intensity being greater than a set... A first edge water intensity threshold is defined, and a first number of production wells are positioned at a third position on the original oil-water interface, and a second number of production wells are positioned at a fourth position on the original oil-water interface; the first number is greater than the second number, and the distance between the fourth position and the original oil-water interface is less than the distance between the third position and the original oil-water interface; in response to the reservoir energy assessment result indicating that the edge water intensity is less than the set second edge water intensity threshold, a row of injection wells is arranged along the original oil-water interface, the injection wells being used to generate edge water drive; the first edge water intensity threshold may be the same as or different from the second edge water intensity threshold.

[0010] According to one embodiment of this application, the step of dynamically adjusting the gas injection parameters of the target gas injection well, the oil production parameters of the target oil production well, and the water injection parameters of the target water injection well based on the production data to obtain the target injection-production parameters includes: adjusting the gas injection intensity of the target gas injection well based on the pressure data to obtain a target gas injection intensity; adjusting the oil production intensity of the target oil production well based on the water cut data and the gas cut data to obtain a target oil production intensity; adjusting the water injection intensity of the target water injection well based on the production data to obtain a target water injection intensity; the water injection intensity, gas injection intensity, and oil production intensity are interrelated; and the target injection-production parameters are determined based on the target gas injection intensity, the target oil production intensity, and the target water injection intensity.

[0011] This application also provides a buried hill reservoir development device, comprising: an evaluation module for evaluating the reservoir characteristics of a target buried hill reservoir and obtaining a comprehensive evaluation result; the comprehensive evaluation result includes structural characteristic evaluation results, reservoir heterogeneity evaluation results, reservoir energy evaluation results, and remaining oil distribution evaluation results; a configuration module for configuring the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation result, thereby obtaining a target three-dimensional well network; the target three-dimensional well network is used to collect data from the target buried hill reservoir; the three-dimensional well network includes gas injection wells, oil production wells, and water injection wells; an adjustment module for real-time monitoring of the target three-dimensional well network, obtaining production data of the target three-dimensional well network, and adjusting the injection and production parameters of each well based on the production data to obtain target injection and production parameters; and a development module for developing the target buried hill reservoir using the target three-dimensional well network based on the target injection and production parameters and the corresponding oil production technology of each well.

[0012] This application also provides an electronic device, including: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the method of the above-described embodiments.

[0013] This application also provides a non-transitory computer-readable storage medium storing computer instructions for causing a computer to perform the method according to the above embodiments.

[0014] The method of this application embodiment assesses the reservoir characteristics of a target buried hill reservoir to obtain a comprehensive assessment result. This comprehensive assessment result includes structural characteristic assessment results, reservoir heterogeneity assessment results, reservoir energy assessment results, and remaining oil distribution assessment results. Based on the comprehensive assessment result, the structure of the three-dimensional well network corresponding to the target buried hill reservoir is configured to obtain a target three-dimensional well network. This target three-dimensional well network is used to collect data from the target buried hill reservoir. The three-dimensional well network includes gas injection wells, oil production wells, and water injection wells. The target three-dimensional well network is monitored in real time to obtain production data. Based on the production data, the injection and production parameters of each well are adjusted to obtain target injection and production parameters. Based on the target injection and production parameters and the corresponding oil production technology for each well, the target three-dimensional well network is used to exploit the target buried hill reservoir. This improves reservoir recovery rate and oil production speed.

[0015] It should be understood that the teachings of this application are not required to achieve all the beneficial effects described above, but rather that a specific technical solution can achieve a specific technical effect, and other embodiments of this application can also achieve beneficial effects not mentioned above. Attached Figure Description

[0016] The above and other objects, features, and advantages of exemplary embodiments of this application will become readily apparent from the following detailed description taken in conjunction with the accompanying drawings. Several embodiments of this application are illustrated in the drawings by way of example and not limitation, in which:

[0017] In the accompanying drawings, the same or corresponding reference numerals indicate the same or corresponding parts.

[0018] Figure 1 This paper illustrates the processing flow of the buried hill oil reservoir exploitation method provided in the embodiments of this application. Figure 1 ;

[0019] Figure 2 This paper illustrates the processing flow of the buried hill oil reservoir exploitation method provided in the embodiments of this application. Figure 2 ;

[0020] Figure 3 This paper illustrates the processing flow of the buried hill oil reservoir exploitation method provided in the embodiments of this application. Figure 3 ;

[0021] Figure 4 This paper illustrates the processing flow of the buried hill oil reservoir exploitation method provided in the embodiments of this application. Figure 4 ;

[0022] Figure 5 This application illustrates an application scenario of the buried hill oil reservoir exploitation method provided in this embodiment. Figure 1 ;

[0023] Figure 6 This illustration shows an optional schematic diagram of a buried hill oil reservoir exploitation apparatus provided in an embodiment of this application;

[0024] Figure 7 A schematic diagram of the composition structure of the electronic device provided in the embodiments of this application is shown. Detailed Implementation

[0025] To make the objectives, features, and advantages of this application more apparent and understandable, the technical solutions in the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, and not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0026] In the following description, references are made to “some embodiments,” which describe a subset of all possible embodiments. However, it is understood that “some embodiments” may be the same subset or different subsets of all possible embodiments and may be combined with each other without conflict.

[0027] In the following description, the terms "first" and "second" are used merely to distinguish similar objects and do not represent a specific ordering of objects. It is understood that "first" and "second" may be interchanged in a specific order or sequence where permitted, so that the embodiments of this application described herein can be implemented in an order other than that illustrated or described herein.

[0028] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein is for the purpose of describing embodiments of this application only and is not intended to limit this application.

[0029] The processing flow in the buried hill reservoir development method provided in the embodiments of this application is described. See also Figure 1 , Figure 1 This is a schematic diagram of the processing flow of the buried hill oil reservoir development method provided in the embodiments of this application. Figure 1 , will combine Figure 1 Steps S101-S104 are explained below.

[0030] Step S101: Conduct reservoir characteristic assessment on the target buried hill reservoir to obtain comprehensive assessment results; the comprehensive assessment results include structural characteristic assessment results, reservoir heterogeneity assessment results, reservoir energy assessment results, and remaining oil distribution assessment results.

[0031] In some embodiments, reservoir characteristic assessment may include evaluations of structural features, reservoir heterogeneity, reservoir energy, and remaining oil distribution. The comprehensive assessment results can be used to characterize the geological and fluid properties of the target buried hill reservoir. The comprehensive assessment results can be used to configure the structure of a three-dimensional well network. Structural feature assessment includes determining structural morphology, fracture systems, and buried hill amplitude, where the buried hill amplitude can be used to configure gravity-driven "high injection, low production" well network components. Reservoir heterogeneity assessment can be used to identify the distribution of high-permeability channels such as fractures and pores. Reservoir energy assessment can be used to determine the intensity of natural water drive. Remaining oil distribution assessment can be used to determine the location and quantity of remaining oil.

[0032] Step S102: Based on the comprehensive evaluation results, the structure of the three-dimensional well network corresponding to the target buried hill reservoir is configured to obtain the target three-dimensional well network; the target three-dimensional well network is used to collect data from the target buried hill reservoir; the three-dimensional well network includes gas injection wells, oil production wells and water injection wells.

[0033] In some embodiments, a three-dimensional well network may include various types of wells, such as gas injection wells, oil production wells, and water injection wells. The wells in the three-dimensional well network can be arranged in a specific order. Gas injection wells can be deployed at the highest point of the buried hill structure to ensure that the injected nitrogen gas preferentially accumulates at the top due to density differences, forming a stable and uniformly depressed gas cap. The location of oil production wells can be determined based on the energy strength of the natural water body in the target buried hill reservoir to achieve long-term stable production. The location of water injection wells can be determined based on reservoir energy assessment results and geological characteristics, and is usually arranged at the bottom or flank of the target buried hill reservoir to replenish formation energy.

[0034] Step S103: Real-time monitoring of the target three-dimensional well network is performed to obtain the production data of the target three-dimensional well network. Based on the production data, the injection and production parameters of each well are adjusted to obtain the target injection and production parameters.

[0035] In some embodiments, production data may include pressure data, production data, water cut data, and gas cut data of each well in the target three-dimensional well network. Injection and production parameters may include gas injection intensity, oil production intensity, and water injection intensity. A real-time monitoring system can periodically collect production data from each well, and based on this data, calculate the optimal combination of gas injection intensity, oil production intensity, and water injection intensity to ensure stable gas cap advancement, uniform oil ring extraction, and oil-water interface control. For example, when an increase in the water cut of a production well is detected, the fluid production rate of that well is reduced, while the water injection intensity of adjacent water injection wells is appropriately increased to obtain the target injection and production parameters, thereby enhancing support for the oil ring and slowing down the formation of a water cone.

[0036] Step S104: Based on the target injection and production parameters and the corresponding oil production technology of each well, the target buried hill oil reservoir is exploited using the target three-dimensional well network.

[0037] In some embodiments, the oil production process may include: profile control and water shut-off processes for gas injection wells, high-volume lift processes for oil production wells, and water control measures for water injection wells.

[0038] As an example, in the development of a typical residual hill unit in a carbonate reservoir in the Tarim Basin, a comprehensive reservoir characteristic assessment was first conducted on the target buried hill reservoir. Using 3D seismic and fine geological modeling techniques, the reservoir's structural morphology, fault system, and buried hill amplitude were determined. Macroscopic parameters such as reservoir porosity and permeability, as well as the microscopic fluid properties of oil, gas, and water, were systematically evaluated, and reservoir heterogeneity was analyzed. The original geological reserves of the reservoir were calculated, and reservoir energy was assessed. Two main remaining oil-rich areas were identified, and the remaining oil distribution was assessed. The comprehensive assessment results include structural characteristic assessment results, reservoir heterogeneity assessment results, reservoir energy assessment results, and remaining oil distribution assessment results. Based on the comprehensive assessment results, a target three-dimensional well network consisting of 3 top gas injection wells, 3 upper-middle oil production wells, and 2 bottom water injection wells was configured. In the target three-dimensional well network, target gas injection wells are deployed at the highest point of the structure to form a unified gas cap; target oil production wells, based on the weak bottom water energy of the target buried hill reservoir, are deployed at approximately 1 / 2 to 2 / 3 of the oil column height to avoid bottom water; target water injection wells are deployed near the original oil-water interface to replenish formation energy. During production, real-time monitoring of production data such as pressure, production, water cut, and gas cut of each well is conducted. Based on the production data, the gas injection intensity of target gas injection wells, the oil production intensity of target oil production wells, and the water injection intensity of target water injection wells are dynamically adjusted. For example, in the initial stage of development, continuous injection is implemented for three months for target gas injection wells, with a designed total injection rate of 50,000 cubic meters per day to quickly form the gas cap; as the formation pressure reaches the target value, the strategy is switched to intermittent balanced injection to maintain the stable advancement of the gas cap. Simultaneously, target water injection wells at the bottom are activated, with the water injection intensity controlled at 80 cubic meters per day to support the oil annulus and delay water flooding of the oil production wells. Through this dynamic adjustment based on production data, the coordinated optimization of gas injection, oil production, and water injection was achieved, enabling the comprehensive daily oil production of the target oil well to be steadily increased and maintained at over 70 tons.

[0039] The method described in this application establishes a systematic design method consisting of four core technologies, ensuring coordinated optimization throughout the entire process from geological assessment to production implementation.

[0040] (1) Comprehensive reservoir assessment method. An assessment system based on key geological parameters is established, in which the size of buried hill structures, reservoir characteristics, and heterogeneity are identified as the core design basis to construct a geological model to guide subsequent development design.

[0041] (2) Three-dimensional well network design method. Design and construct a multi-level three-dimensional well network architecture of "top gas injection, waist oil production, and bottom energy replenishment". This well network makes full use of gravity differentiation, deploying nitrogen injection wells at the top of the buried hill, deploying oil production wells in the middle and lower parts of the reservoir, and optionally using natural water bodies or deploying water injection wells at the bottom for energy replenishment, forming an efficient three-dimensional displacement mode.

[0042] (3) Injection-Production Intensity Design Method. A method for optimizing injection and production parameters based on the principle of material balance and reservoir dynamic response is proposed. This method abandons the traditional continuous injection-production mode and adopts a large-scale, discontinuous periodic injection-production strategy to actively control the formation and stable advancement of the gas cap. Through the closed-loop control of the "three-way linkage" of gas injection, oil production and water injection intensity, the overall benefits are maximized.

[0043] (4) Supporting technology design. Establish a technical system that systematically applies auxiliary technologies such as foam, foam acid, and water shut-off agents at different stages of development. This system aims to dynamically control fluid flow direction, seal high-permeability channels, improve sweep uniformity, and achieve refined management of the reservoir.

[0044] This three-dimensional oil recovery model, characterized by "top nitrogen injection, mid-section oil production, and bottom energy replenishment," maximizes the synergistic effect of gravity differentiation and gas-driven oil recovery, significantly improving the recovery rate of buried hill reservoirs. It can increase the recovery rate of similar buried hill reservoirs from approximately 20% with conventional waterflooding to 40%-50% or even higher. Through early gas injection for pressure building and optimized injection-production synergy, it can significantly improve the oilfield's production rate and daily oil production. Taking a residual hill unit in a buried hill reservoir as an example, after gas injection, the daily production of key wells increased from 5 tons to 24 tons, resulting in a cumulative increase of 18,000 tons of oil. By combining a three-dimensional well network, dynamic injection-production, and supporting auxiliary technologies, active control over gas-top propulsion, the oil-water interface, and fluid flow is achieved, making the management of the entire development process more refined, controllable, and predictable, laying the foundation for large-scale application.

[0045] In some embodiments, the processing flow of the buried hill reservoir exploitation method is illustrated. Figure 2 ,like Figure 2 As shown, step S101, which involves evaluating the reservoir characteristics of the target buried hill reservoir to obtain a comprehensive evaluation result, may include:

[0046] Step S201: Conduct a structural feature assessment of the target buried hill reservoir to obtain the structural feature assessment results.

[0047] As an example, structural feature assessment can include determining the buried hill amplitude (height difference), fracture system, and structural morphology. Specifically, the buried hill amplitude is the most critical parameter, a prerequisite for gravity-driven "high injection, low production" well patterns, as it enables effective gravity sorting and directly impacts the vertical layout and recovery efficiency of the 3D well pattern. Through 3D seismic analysis and detailed geological modeling, the development and connectivity of fractures, caverns, and cavities within the target buried hill reservoir can be determined. This allows for the identification of the fracture system and structural morphology.

[0048] As an example, based on 3D seismic data, through detailed geological modeling and interpretation, the amplitude of buried hills, fault systems, and structural morphology are derived.

[0049] Specifically, tectonic morphology and buried hill size can be identified by interpreting key seismic reflection horizons, such as the top of the Ordovician (T74). By mapping key seismic reflection horizons in 3D space, creating structural maps (e.g., tectonic maps of the T74 time period) and cross-sectional maps can reveal the morphology, peaks, and valleys of the buried hill. The vertical distance from the peak to the foot of the hill on the structural maps and cross-sectional maps can be obtained and determined as the buried hill size.

[0050] The faults included in the fault system can appear as discontinuities or breaks in the seismic reflector. Seismic properties, such as coherence or amplitude variance (e.g., the 0-20ms AFE property map of the T402 karst hillock), are calculated from the 3D seismic volume. The corresponding fault network is then determined based on the seismic properties and faults, thus obtaining the fault system.

[0051] Step S202: The target buried hill reservoir is subjected to reservoir heterogeneity assessment to obtain the reservoir heterogeneity assessment results.

[0052] As an example, reservoir heterogeneity assessment can include identifying the distribution of high-permeability channels such as fractures and pores. Specifically, high-permeability channels are the main pathways for gas and water flow, and their characteristics determine the application points of subsequent auxiliary oil recovery technologies (such as foam plugging) and the optimization direction of the three-dimensional well network. Reservoir heterogeneity assessment results can include macroscopic reservoir parameters and microscopic fluid parameters. Macroscopic reservoir parameters can include macroscopic parameters such as reservoir porosity, permeability, and saturation. Microscopic fluid parameters can include the microscopic fluid properties of oil, gas, and water.

[0053] Step S203: Conduct reservoir energy assessment on the target buried hill reservoir to obtain reservoir energy assessment results.

[0054] As an example, reservoir energy assessment can be used to determine the intensity of natural water drive in a target buried hill reservoir. Specifically, the reservoir energy assessment results can include bottom water intensity and edge water intensity. Bottom water intensity characterizes the energy of the bottom natural water body in the target buried hill reservoir. Edge water intensity characterizes the energy of the edge natural water body in the target buried hill reservoir.

[0055] As an example, bottom water strength is determined by analyzing dynamic and static data. Specifically, pressure data is analyzed, i.e., long-term monitoring of reservoir pressure during production. A slow pressure drop under heavy pumping indicates strong waterflooding, while a rapid pressure drop indicates weak waterflooding. Geological data is analyzed, i.e., the size and connectivity of aquifers connected to the reservoir. Large, well-connected aquifers identified through regional geological studies and seismic data will provide strong pressure support. Production dynamic data is analyzed, i.e., whether the water intrusion rate in existing wells and the oil-water interface show an increase over time. A rapid and uniform increase in the oil-water interface is an indicator of strong bottom waterflooding.

[0056] The limitations of edge water strength are similar to those of bottom water strength, and it is mainly determined through the following methods: Analyzing pressure data, i.e., analyzing the pressure gradient across the entire area, to obtain the edge water strength. Analyzing production dynamic data, i.e., determining the edge water strength based on the initial water production location on the structural flank of the reservoir and the advance velocity of the water front. Analyzing geological data, i.e., determining the edge water strength based on the connection diagram between the reservoir and lateral aquifers.

[0057] Step S204: Assess the remaining oil distribution of the target buried hill reservoir and obtain the remaining oil distribution assessment results.

[0058] As an example, residual oil distribution assessment can include determining the location and quantity of residual oil-rich areas. Specifically, based on the results of structural feature assessment and reservoir heterogeneity assessment, the original geological reserves of the target buried hill reservoir are calculated, and residual oil-rich areas are identified. Taking the Tarim River S65 well area as an example, two residual oil-rich areas with reserves of 190,000 tons and 454,000 tons, respectively, were identified.

[0059] As an example, calculating the original geological reserves of a target buried hill reservoir and identifying areas of remaining oil enrichment may include:

[0060] Calculating Original Out-of-Potential (OOIP): OOIP is calculated using the industry-standard volumetric method. The formula for the industry-standard volumetric method involves multiplying the reservoir's rock volume (area × thickness), porosity, and oil saturation (1 - water saturation), then dividing by the reservoir volume factor (FVF). The inputs for this calculation are directly derived from structural feature assessments and reservoir heterogeneity assessments. Area and thickness can be obtained from geological maps, such as isopyrographs (e.g., "Reservoir Thickness Distribution Map"). Porosity and water saturation can be obtained from well logging analysis and core data.

[0061] Identifying Remaining Oil Concentration Zones: Remaining oil concentration zones are identified by integrating static and dynamic data. The original oil distribution map is overlaid with data from areas that have been washed away by water or gas. Areas that have not been effectively washed away and still contain high oil saturation are identified as remaining oil concentration zones. These zones are typically identified based on reservoir simulation models or by analyzing production history and pressure data.

[0062] In some embodiments, the processing flow of the buried hill reservoir exploitation method is illustrated. Figure 3 , like Figure 3 As shown, in step S102, based on the comprehensive evaluation results, the structure of the three-dimensional well network corresponding to the target buried hill reservoir is configured to obtain the target three-dimensional well network, which may specifically include:

[0063] Step S301: Based on the structural feature assessment results and the remaining oil distribution assessment results, configure the location and number of gas injection wells to obtain the target gas injection wells.

[0064] As an example, the data used in configuring gas injection wells include structural feature assessment results and remaining oil distribution assessment results. Specifically, the structural feature assessment results refer to data from the top of the structure. This data is used to determine the location of the gas injection wells. The injection wells can be located at the highest point of the structure so that the injected nitrogen forms a stable, gravity-driven gas cap. The remaining oil distribution assessment results are used to determine the number of gas injection wells required to process the remaining oil reserves, effectively covering the entire remaining oil-rich area. This ultimately leads to the configuration of target gas injection wells, which can be newly built dedicated gas injection wells or existing production wells converted from structurally high locations.

[0065] Step S302: Based on the reservoir energy assessment results and the remaining oil distribution assessment results, configure the vertical position of the wellbore perforation and the planar position of the oil production well to obtain the target oil production well.

[0066] As an example, the data used in configuring oil wells include reservoir energy assessment results and remaining oil distribution assessment results. Specifically, the reservoir energy assessment results can be used to determine the vertical position of the wellbore perforations. If the bottom water intensity is low, the vertical position of the wellbore perforations is positioned in the upper-middle part of the oil column height; if the bottom water intensity is high, the vertical position of the wellbore perforations is positioned in the lower-middle part of the oil column height. The remaining oil distribution assessment results can be used to determine the planar position (regional position) of the oil wells, ensuring that the oil wells can exploit areas rich in remaining oil, ultimately resulting in the target oil well configuration.

[0067] Step S303: Based on the reservoir energy assessment results and reservoir heterogeneity assessment results, configure the location and number of water injection wells to obtain the target water injection wells.

[0068] As an example, the data used in configuring water injection wells include reservoir energy assessment results and reservoir heterogeneity assessment results. The reservoir heterogeneity assessment results can include the location of the original oil-water interface in the geological model corresponding to the target buried hill reservoir. The reservoir energy assessment results are used to determine the necessity of water injection and the number of injection wells. If the natural energy is weak, water injection wells are required. The location of the water injection wells is determined based on the original oil-water interface; the water injection wells can be configured above or below the original oil-water interface. Finally, the target water injection wells are configured. The water injection wells provide pressure support to the oil ring from below, ensuring a stable displacement process.

[0069] As an example, the initial oil-water interface is determined using multiple data sources before large-scale production. Specifically, the initial oil-water interface can be determined based on well logging data. Resistivity logging data from the first well in an oilfield can show a sharp change from high resistivity (oil-bearing layer) to low resistivity (water-bearing layer). The depth at which this sharp change occurs is the initial oil-water interface. The initial oil-water interface can also be determined based on drilling data. The comparison between oil / gas and water encountered during drilling can determine the contact depth, which is the initial oil-water interface. Alternatively, the initial oil-water interface can be determined based on pressure data. Pressure measurements at different depths within the well can show changes in the fluid pressure gradient. Based on these changes, the depth at which the fluid column changes from oil to water can be determined, which is the initial oil-water interface. Finally, the initial oil-water interface can be determined based on seismic data. In some cases, a "flat point" can be observed on a seismic profile. This "flat point" is a horizontal seismic reflector, and the depth corresponding to the "flat point" is the initial oil-water interface.

[0070] Step S304: Based on the target gas injection well, target oil production well, and target water injection well, construct the target three-dimensional well network.

[0071] As an example, during the exploitation of the target buried hill oil reservoir, a three-dimensional well network was constructed by integrating 3 gas injection wells, 5 oil production wells, and 2 water injection wells, establishing an effective "high injection, low production, and bottom energy replenishment" configuration. Based on comprehensive evaluation results, the target three-dimensional well network was constructed using 3 gas injection wells, 5 oil production wells, and 2 water injection wells. This layout achieves efficient injection-production linkage, with gas injection wells forming a stable gas cap, oil production wells effectively extracting oil, and water injection wells replenishing energy to maintain a stable oil-water interface.

[0072] In some embodiments, the buried hill reservoir development method further includes: in response to the reservoir energy assessment result including bottom water intensity being greater than a set first bottom water intensity threshold, configuring a vertical position at a first position corresponding to the oil column height of the production well; in response to the reservoir energy assessment result including bottom water intensity being less than a set second bottom water intensity threshold, configuring a vertical position at a second position corresponding to the oil column height of the production well; the first bottom water intensity threshold and the second bottom water intensity threshold are the same or different; the first position is lower than the second position; in response to the reservoir energy assessment result including edge water intensity being greater than a set first edge water intensity threshold, configuring a first number of production wells at a third position on the original oil-water interface, and configuring a second number of production wells at a fourth position on the original oil-water interface; the first number is greater than the second number, and the distance between the fourth position and the original oil-water interface is less than the distance between the third position and the original oil-water interface; in response to the reservoir energy assessment result including edge water intensity being less than a set second edge water intensity threshold, arranging a row of injection wells along the original oil-water interface, the injection wells being used to generate edge water drive; the first edge water intensity threshold and the second edge water intensity threshold are the same or different.

[0073] In some embodiments, the first bottom water strength threshold may include a preset bottom water strength standard value. The second bottom water strength threshold may include another preset bottom water strength standard value. The first bottom water strength threshold and the second bottom water strength threshold may be the same or different. The vertical position may include the specific location of the oil well in the direction of the oil column height. If the bottom water strength is greater than the set first bottom water strength threshold, the vertical position is configured in the lower middle part of the oil column height (approximately 1 / 3 to 1 / 2 of the height); if the bottom water strength is less than the set second bottom water strength threshold, the vertical position is configured in the upper middle part of the oil column height (approximately 1 / 2 to 2 / 3 of the height).

[0074] In some embodiments, the first edge water intensity threshold may include a preset edge water intensity standard value. The second edge water intensity threshold may include another preset edge water intensity standard value, which can be used as a basis for further judging edge water energy. The first edge water intensity threshold and the second edge water intensity threshold may be the same or different. The planar location may include the specific layout location of the oil wells on the reservoir horizontal plane. The distance between the oil wells and the original oil-water interface is adjusted according to the edge water intensity, or water injection wells are arranged to form edge water drive. The first quantity may include the number of oil wells deployed on the inner side of the reservoir away from the edge water invasion direction. The first quantity is greater than the second quantity. The second quantity may include the number of some "outpost" oil wells deployed in the area close to the original oil-water interface. The "outpost" oil wells can be used to monitor and control the leading edge area of ​​edge water advance when the edge water intensity is high. If the edge water intensity is less than the set first edge water intensity threshold, a row of water injection wells is arranged along the original oil-water interface on the reservoir flank. The water injection wells are used to supplement the pressure support lacking in the natural aquifer to form edge water drive. Edge waterflooding can be used to enhance the waterflooding effect at the reservoir edge when the edge water strength is insufficient, thereby maintaining reservoir pressure and production efficiency.

[0075] As an example, in a buried hill reservoir development project, the reservoir energy is first assessed. If the assessment indicates that the bottom water strength is greater than the set first bottom water strength threshold (e.g., 15 MPa), the vertical position of the wellbore perforation corresponding to the production well is configured in the lower-middle part of the oil column height (approximately 1 / 3 to 1 / 2 of the height) to fully utilize the strong bottom water strength to push the oil annulus upward and slow down the gas cap cone velocity. Conversely, if the bottom water strength is less than the set second bottom water strength threshold (e.g., 10 MPa), the vertical position of the wellbore perforation corresponding to the production well is configured in the upper-middle part of the oil column height (approximately 1 / 2 to 2 / 3 of the height) to stay away from the oil-water interface and avoid premature water flooding.

[0076] Regarding the handling of edge water intensity, if the edge water intensity exceeds a set first edge water intensity threshold (e.g., 20 MPa), then most (the first number, e.g., 80%) of the production wells will be positioned on the inner side of the reservoir away from the edge water intrusion direction (third position) to fully exploit the reservoir area in the edge water drive direction. Simultaneously, a small number (the second number, e.g., 20%) of production wells will be positioned on the inner side (fourth position) near the original oil-water interface to monitor and control edge water drive. If the edge water intensity is less than a set second edge water intensity threshold (e.g., 10 MPa), then a row of injection wells will be arranged along the original oil-water interface on the reservoir flank to form edge water drive.

[0077] In some embodiments, the processing flow of the buried hill reservoir exploitation method is illustrated. Figure 4 , like Figure 4 As shown, methods for developing buried hill oil reservoirs may include:

[0078] Step S401: Based on production data, dynamically adjust the gas injection parameters of the target gas injection well, the oil production parameters of the target oil production well, and the water injection parameters of the target water injection well to obtain the target injection-production parameters.

[0079] In this embodiment, production data such as pressure, production rate, water cut, and gas cut of each well in the target three-dimensional well network are monitored in real time. Based on this production data, the parameters of gas injection wells, oil production wells, and water injection wells are dynamically adjusted. For example, if the water cut of an oil production well increases, the fluid production rate of that well is reduced, while the water injection intensity of adjacent water injection wells is increased to enhance oil ring support and slow down water cone formation; if the reservoir pressure decreases, the gas injection rate of gas injection wells is increased to replenish energy. Through these adjustments, the target injection and production parameters are ultimately balanced. Dynamic adjustment means that the operation of the entire system is a dynamically adjusted closed loop. That is, by monitoring the pressure, production rate, water cut, and gas cut data at the wellhead and downhole in real time, combined with tracers, noise monitoring, and other means, the gas injection parameters, oil production parameters, and water injection parameters are continuously adjusted to achieve the best matching and synergistic effect among the three.

[0080] In some embodiments, step S401, which involves dynamically adjusting the gas injection parameters of the target gas injection well, the oil production parameters of the target oil production well, and the water injection parameters of the target water injection well based on production data to obtain target injection-production parameters, includes: adjusting the gas injection intensity of the target gas injection well based on pressure data to obtain target gas injection intensity; adjusting the oil production intensity of the target oil production well based on water cut data and gas cut data to obtain target oil production intensity; adjusting the water injection intensity of the target water injection well based on production data to obtain target water injection intensity; the water injection intensity, gas injection intensity, and oil production intensity are interrelated; and the target injection-production parameters are determined based on the target gas injection intensity, target oil production intensity, and target water injection intensity.

[0081] As an example, the injection intensity of the target injection well is adjusted based on pressure data to obtain the target injection intensity. Specifically, the design principle for the injection intensity is "smooth pressure build-up and uniform advancement." The initial injection rate can be relatively high to quickly form an effective gas cap; after the gas cap is formed, the injection rate should be switched to a stable rate that matches the production rate.

[0082] The calculation of the target gas injection intensity is a two-stage process, with different injection volumes and rates in each stage. The main methods used are the principle of mass balance and numerical simulation.

[0083] The first stage is to form an effective gas cap. Injection intensity can include the total gas volume and injection rate. The total volume, i.e., the required nitrogen volume, is calculated based on the mass balance equation. The goal is to inject enough gas to raise the average reservoir pressure from its current state to a predetermined target pressure (e.g., from 15 MPa to 18 MPa). This calculation takes into account the compressibility of gas, oil, water, and rock. This volume constitutes the total injection volume (total volume) for the initial pressurization stage. The initial injection rate is determined by the following factors: ① Target pressure and pressurization time: Determine the total gas volume required to reach the target pressure (e.g., 18 MPa). Determine the planned injection time based on the project schedule (e.g., three months). Based on the mass balance calculation, the initial injection rate is the total volume divided by the planned injection time. ② Injection capacity: Injection capacity refers to the reservoir's ability to accept gas without fracturing the rock. Injection capacity can be estimated by performing well tests (injection capacity testing) on ​​the injection well. The initial injection rate must not exceed the injection capacity. ③ Equipment capacity: Equipment capacity refers to the maximum rate at which surface compressors and pipelines deliver nitrogen to the wellhead. The initial injection rate must not exceed the equipment capacity.

[0084] The second stage is the stable displacement front after the gas cap forms. The injection intensity can be measured by the total gas volume and the stable injection rate. Total volume: This is not a fixed volume, but rather the injected volume throughout the entire acquisition process. Injection rate: The stable injection rate in this stage differs significantly from that in the first stage. The stable injection rate in this stage matches the total amount of fluids (oil and water) produced in the reservoir. This is called "porosity replacement." The principle of porosity replacement is to maintain stable reservoir pressure and ensure that the gas cap advances downward in a controlled and uniform manner. The injection process can be switched from continuous to intermittent to achieve the desired average injection rate while maintaining stability.

[0085] The stable injection rate is determined by the porosity replacement principle, meaning the volume of injected fluid matches the volume of produced fluid. The stable injection rate is determined by the following factors: ① Total produced fluid volume: the total amount of oil and water produced by all wells per unit time. ② Reservoir pressure: The stable injection rate refers to the rate required to maintain a constant average reservoir pressure. If the reservoir pressure decreases, the injection rate is increased; if the reservoir pressure rises too quickly, the injection rate is decreased. The goal is to achieve equilibrium, i.e., pressure stabilization. ③ Numerical simulation: Predicting the stable injection rate required to maintain reservoir pressure under different production conditions using reservoir data models.

[0086] To avoid excessive pressure leading to gas cap instability and rapid flow along large fractures, "early injection" can be used. This involves injecting nitrogen in the early stages of oilfield development to establish a gas cap as early as possible using gravity differentiation, which can maximize sweep efficiency and total recovery rate.

[0087] As an example, the oil production intensity of the target well is adjusted based on water cut and gas cut data to obtain the target oil production intensity. Specifically, the oil production intensity of the target well is controlled to maintain a stable oil ring and avoid gas cap coning or water flooding. By dynamically monitoring the gas cut and water cut of the target well, the oil production intensity is adjusted in reverse to obtain the target oil production intensity, thereby maximizing the overall reservoir benefits.

[0088] Reverse adjustment of oil production intensity refers to a feedback loop that uses output (production data) to control input (oil production intensity), which is a dynamic management process.

[0089] Taking gas coning as an example: If the gas cut (gas-oil ratio, GOR) of the target well begins to increase sharply, it indicates that the gas cap is being pulled down into the well too quickly, resulting in gas coning. The production intensity of the corresponding target well should be reduced. Specifically, this is done by adjusting the fluid production rate, such as by restricting flow at the surface or reducing the speed of the electric submersible pump (ESP). Taking water coning as an example: If the water cut of the target well begins to increase, it indicates that water at the bottom is being pulled down into the well too quickly, resulting in water coning. The production intensity of the corresponding target well should be reduced. Specifically, this is done by reducing the fluid production rate of the target well to decrease pressure drop and reduce the size of the water coning.

[0090] As an example, the target water injection intensity is obtained by adjusting the water injection intensity of the target injection well based on production data. Specifically, during oil production, the adjustment of water injection intensity is usually carried out simultaneously with the adjustment of oil production intensity, or the adjustment is initiated when the pressure drops to a certain preset threshold. Water injection intensity is linked to gas injection intensity and oil production intensity. The goal of adjusting water injection intensity is to maintain pressure and support the oil ring. For example, if the gas injection rate is stable, but the overall reservoir pressure begins to decline, that is, the overall production exceeds the overall injection rate (gas + water), indicating insufficient bottom energy support. In this case, the water injection intensity is increased, that is, the water injection rate of the bottom injection wells is increased to compensate for the insufficient overall reservoir pressure and provide stronger support for the oil-water interface.

[0091] In some embodiments, if the water cut of the target oil well increases, in addition to reducing the oil production intensity of the corresponding target oil well, the water injection intensity of the target water injection well adjacent to the target oil well can also be reduced to slow down the local water propagation.

[0092] Step S402: Based on the target injection and production parameters and the corresponding oil production technology of each well, the target buried hill oil reservoir is exploited using the target three-dimensional well network.

[0093] In this embodiment, the oil production process includes: profile control and water shut-off process for the target gas injection well, lift process for the target oil production well, and water control measures for the target water injection well.

[0094] As an example, the profile control and water shut-off process for target gas injection wells aims to address the problem of nitrogen easily flowing along large fractures at the top of buried hills, leading to low sweep efficiency. Specifically, this can be achieved by injecting foam or foam acid into the injection well for temporary plugging. Foam can selectively block large, highly permeable fractures, forcing subsequently injected nitrogen to flow into medium- and low-permeability zones and matrix pores, thereby expanding the swept volume of gas drive and achieving the goal of "blocking the main pathways and opening the secondary pathways." The "main pathways" refer to high-permeability channels, including major fault zones, karst conduits, and large caverns. Without profile control and water shut-off, natural gas and water would preferentially flow through these high-permeability channels. The "secondary pathways" refer to the less permeable portions of the reservoir matrix, including matrix pores and a network of smaller, poorly connected microfractures. The goal of the profile control and water shut-off process is to block the "main pathways," forcing gas to flow through the "secondary pathways."

[0095] The lifting technology for target oil wells can be a high-volume lifting technology. High-volume lifting refers to the process where, as development progresses, especially in reservoirs with strong bottom water energy, production and water cut gradually increase, requiring a sufficient lifting capacity to economically and effectively extract crude oil. Configuring a corresponding high-volume lifting system (such as a high-speed submersible pump) for the target oil well ensures that sufficient production intensity is maintained even in the high water-cut stage, effectively extracting crude oil from the oil annulus.

[0096] Water control measures for target injection wells aim to address the problem of premature or rapid water flooding in oil production wells. Layered water injection or chemical plugging measures are employed to ensure that injected water uniformly replenishes formation energy, rather than being ineffectively circulated along high-permeability channels. Layered water injection is a mechanical method that uses specialized downhole tools (such as packers) to isolate different vertical layers or regions within the reservoir. The injection volume for different vertical layers or regions can be adjusted. Chemical plugging involves injecting chemicals such as polymers or gels. These chemicals react within the reservoir to block high-permeability channels. Specifically, the chemicals can enter high-permeability channels and then react, solidifying or expanding to block them.

[0097] refer to Figure 5 Application scenarios of the buried hill oil reservoir development method provided in this application embodiment Figure 1 It is applied to the implementation process of underground hill oil reservoir development.

[0098] Process S1: Comprehensive Reservoir Assessment. In a typical residual hill unit of carbonate reservoirs in the Tarim Basin, a comprehensive reservoir assessment was conducted using a series of geological maps, including reservoir thickness distribution maps, injection-production relationship and reserve distribution maps, and structural elevation distribution maps. The assessment results determined the macroscopic distribution of the reservoir, the degree of heterogeneity, and the location of structural elevations, identifying two main remaining oil-rich areas. This provides a geological basis for subsequent well pattern adjustments and parameter design.

[0099] Process S2: Construction of a Three-Dimensional Well Network. Addressing the weak natural bottom water energy of the residual hill unit, a three-dimensional well network was constructed, consisting of three top gas injection wells (A-1, A-2, A-3), three upper-middle oil production wells (B-1, B-2, B-3), and two bottom water injection wells (C-1, C-2). Gas injection wells were deployed at the highest point of the structure to form a unified gas cap, oil production wells were deployed at approximately 1 / 2 to 2 / 3 of the oil column height, away from the bottom water, and water injection wells were deployed near the oil-water interface to replenish formation energy. During implementation, after gas injection at higher locations, downstream oil production wells gradually became effective from high to low, and the overall oil-water interface gradually decreased, achieving overall utilization of the remaining surface oil.

[0100] Process S3, Injection-Production Intensity Design. In this case of a residual hill unit, the initial development phase is a high-intensity pressure-building stage. Three top gas injection wells (A-1, A-2, A-3) undergo continuous injection for three months, with a designed total injection rate of 50,000 cubic meters per day. The aim is to quickly form a gas cap and occupy the structural high point, restoring the formation pressure from the initial 15 MPa to the target pressure of 18 MPa. During this stage, three production wells (B-1, B-2, B-3) produce at a controlled low fluid yield to coordinate with the rapid pressure recovery. Once the formation pressure reaches the target value, the process transitions to a stable displacement stage. At this point, the gas injection strategy changes from "continuous" to "intermittent balanced injection." That is, based on production dynamics, the gas injection equipment is activated daily or every few days, intermittently injecting at a high rate of 50,000 cubic meters per day to maintain an average daily injection level of 25,000-30,000 cubic meters per day, ensuring a smooth and uniform downward push of the gas cap. Simultaneously, two bottom water injection wells (C-1 and C-2) were activated, with the total water injection intensity controlled at 80 cubic meters per day. The aim was to provide effective pressure support for the central oil annulus, precisely control the uplift rate of the oil-water interface, and thus delay water flooding of the production wells. Throughout the production process, the pressure, production, water cut, and gas cut of each well were analyzed weekly using a real-time monitoring system. For example, when the water cut of well B-2 showed an upward trend, the water injection intensity of the adjacent well C-1 was appropriately increased, while the production rate of well B-2 was appropriately reduced to enhance support for the oil annulus and slow down the formation of a water cone. Conversely, when the pressure of well B-3 dropped rapidly, the nitrogen injection distribution of well A-2 was appropriately increased to enhance the gas drive energy in that direction. Through this precise "three-way linkage" control, the combined daily oil production of the three production wells steadily increased from an initial total of 25 tons and remained above 70 tons, while the combined water cut was successfully controlled within the expected range. After two years of implementation, a total of over 20 million cubic meters of nitrogen gas was injected. Based on the real gas law and the fluid characteristics of the reservoir, under formation pressure of 55 MPa and temperature of 130°C, the volume compressibility ratio of nitrogen gas was calculated to be approximately 310:1. This means that 1000 standard cubic meters of nitrogen gas injected into the formation occupies an effective displacement volume of approximately 3.22 cubic meters in the reservoir. Therefore, the 20 million standard cubic meters of gas injected in this case created an effective displacement volume of approximately 64,400 cubic meters underground, ultimately resulting in a cumulative increase in oil production of 58,000 tons. This demonstrates the significant effectiveness of this co-design method in improving oil production rate and controlling water cut.

[0101] According to S4, auxiliary processes were implemented. After approximately six months of stable gas injection, the reservoir's heterogeneity led to severe gas channeling between wells A-1 and B-1. Specifically, the casing pressure at the wellhead of well B-1 rapidly increased from 52 MPa to 56 MPa, the gas-oil ratio surged from the normal 50 m³ / t to over 2000 m³ / t, and oil production plummeted; while the adjacent production well B-2 showed insufficient pressure response and no significant change in production. Inter-well connectivity testing using tracer injection confirmed the existence of a large, highly conductive fracture between A-1 and B-1, causing ineffective gas circulation. To address this issue, a nitrogen foam temporary plugging and control process was implemented in injection well A-1. The design employed a high-strength colloidal foam system, using a "small dose, multiple cycles" injection method. First, 2000 standard cubic meters of nitrogen-generated foam slugs were injected into well A-1. Utilizing the extremely high flow resistance formed by the foam liquid in the high-permeability fracture, this dominant channel was selectively plugged. Subsequently, normal nitrogen injection was resumed, forcing subsequent gas to bypass the blocked dominant channels and redirect towards the previously unreached medium- and low-permeability reservoir areas. The foam-driven flow control proved highly effective. A week later, the gas-oil ratio in well B-1 rapidly dropped below 1000 m³ / t, and production returned to normal. A month later, the bottomhole pressure in well B-2, which had previously shown slow results, began to rise steadily, and daily oil production increased from 18 tons to 26 tons, indicating that the gas-driven flow direction had been successfully redirected. This is a key guarantee for achieving the goal of "blocking the main channels and opening the side channels" in buried hill reservoirs, significantly improving flow efficiency and ultimate recovery.

[0102] The following continues to describe the exemplary structure of the software modules included in the buried hill oil reservoir development apparatus 90 provided in the embodiments of this application. In some embodiments, such as Figure 6 As shown, the buried hill oil reservoir development unit 90 may include:

[0103] Evaluation module 901 is used to evaluate the reservoir characteristics of the target buried hill reservoir and obtain comprehensive evaluation results. The comprehensive evaluation results include structural feature evaluation results, reservoir heterogeneity evaluation results, reservoir energy evaluation results, and remaining oil distribution evaluation results.

[0104] Configuration module 902 is used to configure the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation results, so as to obtain the target three-dimensional well network; the target three-dimensional well network is used to collect data from the target buried hill reservoir; the three-dimensional well network includes gas injection wells, oil production wells and water injection wells;

[0105] The adjustment module 903 is used to monitor the target three-dimensional well network in real time, obtain the production data of the target three-dimensional well network, and adjust the injection and production parameters of each well based on the production data to obtain the target injection and production parameters.

[0106] The extraction module 904 is used to extract target buried hill oil reservoirs using the target three-dimensional well network based on target injection and production parameters and the corresponding oil production technology of each well.

[0107] In some embodiments, the evaluation module 901 can be used to: evaluate the structural characteristics of the target buried hill reservoir to obtain structural characteristic evaluation results; the structural characteristic evaluation results include structural morphology, fracture system, and buried hill amplitude; evaluate the reservoir heterogeneity of the target buried hill reservoir to obtain reservoir heterogeneity evaluation results; the reservoir heterogeneity evaluation results include macroscopic reservoir parameters and microscopic fluid parameters; evaluate the reservoir energy of the target buried hill reservoir to obtain reservoir energy evaluation results; the reservoir energy evaluation results include bottom water intensity and edge water intensity; evaluate the remaining oil distribution of the target buried hill reservoir to obtain remaining oil distribution evaluation results; the remaining oil distribution evaluation results include remaining oil enrichment areas and remaining oil reserves.

[0108] In some embodiments, the configuration module 902 can be used to: configure the location and number of gas injection wells based on the structural feature assessment results and the remaining oil distribution assessment results to obtain target gas injection wells; configure the vertical position of the wellbore perforations and the planar position of the production wells based on the reservoir energy assessment results and the remaining oil distribution assessment results to obtain target production wells; configure the location and number of water injection wells based on the reservoir energy assessment results and the reservoir heterogeneity assessment results to obtain target water injection wells; and construct a target three-dimensional well network based on the target gas injection wells, target production wells, and target water injection wells.

[0109] In some embodiments, the production data includes pressure data, production data, water cut data, and gas cut data corresponding to the target three-dimensional well network; the target three-dimensional well network includes target gas injection wells, target oil production wells, and target water injection wells; the adjustment module 903 can be used to: dynamically adjust the gas injection parameters of the target gas injection wells, the oil production parameters of the target oil production wells, and the water injection parameters of the target water injection wells based on the production data to obtain target injection and production parameters.

[0110] In some embodiments, the oil production process includes: profile control and water shut-off process for the target gas injection well, lift process for the target oil production well, and water control measures for the target water injection well.

[0111] In some embodiments, the configuration module 902 may be used to: in response to the reservoir energy assessment result including bottom water intensity being greater than a set first bottom water intensity threshold, configure the vertical position at a first position at the oil column height corresponding to the production well; in response to the reservoir energy assessment result including bottom water intensity being less than a set second bottom water intensity threshold, configure the vertical position at a second position at the oil column height corresponding to the production well; the first bottom water intensity threshold and the second bottom water intensity threshold may be the same as or different; the first position is lower than the second position; in response to the reservoir energy assessment result including edge water intensity being greater than a set first edge water intensity threshold, configure the planar position of a first number of production wells at a third position at the original oil-water interface, and configure the planar position of a second number of production wells at a fourth position at the original oil-water interface; the first number is greater than the second number, and the distance between the fourth position and the original oil-water interface is less than the distance between the third position and the original oil-water interface; in response to the reservoir energy assessment result including edge water intensity being less than a set second edge water intensity threshold, arrange a row of water injection wells along the original oil-water interface, the water injection wells being used to generate edge water drive; the first edge water intensity threshold and the second edge water intensity threshold may be the same as or different.

[0112] In some embodiments, the adjustment module 903 can be used to: adjust the gas injection intensity of the target gas injection well according to pressure data to obtain the target gas injection intensity; adjust the oil production intensity of the target oil production well according to water cut data and gas cut data to obtain the target oil production intensity; adjust the water injection intensity of the target water injection well according to production data to obtain the target water injection intensity; the water injection intensity, gas injection intensity, and oil production intensity are interrelated; and determine the target injection and production parameters based on the target gas injection intensity, target oil production intensity, and target water injection intensity.

[0113] It should be noted that the description of the apparatus in this application embodiment is similar to the description of the method embodiment above, and has similar beneficial effects as the method embodiment, therefore it will not be repeated. For any technical details not covered in the buried hill reservoir development apparatus provided in this application embodiment, please refer to... Figures 1 to 5 The meaning is understood in accordance with the description of any of the accompanying drawings.

[0114] According to embodiments of this application, this application also provides an electronic device and a non-transitory computer-readable storage medium.

[0115] Figure 7A schematic block diagram of an example electronic device 800 that can be used to implement embodiments of this application 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 may also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices, 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 application described and / or claimed herein.

[0116] like Figure 7 As shown, the electronic device 800 includes a computing unit 801, which can perform various appropriate actions and processes based on a computer program stored in a read-only memory (ROM) 802 or a computer program loaded from a storage unit 808 into a random access memory (RAM) 803. The RAM 803 may also store various programs and data required for the operation of the electronic device 800. The computing unit 801, ROM 802, and RAM 803 are interconnected via a bus 804. An input / output (I / O) interface 805 is also connected to the bus 804.

[0117] Multiple components in electronic device 800 are connected to I / O interface 805, including: input unit 806, such as keyboard, mouse, etc.; output unit 807, such as various types of displays, speakers, etc.; storage unit 808, such as disk, optical disk, etc.; and communication unit 809, such as network card, modem, wireless transceiver, etc. Communication unit 809 allows electronic device 800 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0118] The computing unit 801 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of the computing unit 801 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 computing units running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. The computing unit 801 performs the various methods and processes described above, such as buried hill reservoir exploitation methods. For example, in some embodiments, the buried hill reservoir exploitation method can be implemented as a computer software program tangibly contained in a machine-readable medium, such as storage unit 808. In some embodiments, part or all of the computer program can be loaded and / or installed on the electronic device 800 via ROM 802 and / or communication unit 809. When the computer program is loaded into RAM 803 and executed by the computing unit 801, one or more steps of the buried hill reservoir exploitation method described above can be performed. Alternatively, in other embodiments, the computing unit 801 can be configured to perform the buried hill reservoir exploitation method by any other suitable means (e.g., by means of firmware).

[0119] 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.

[0120] The program code used to implement the methods of this application may be written in any combination of one or more programming languages. This program code may be provided to a processor or controller of a general-purpose computer, special-purpose computer, or other programmable data processing device, such that when executed by the processor or controller, the functions / operations specified in the flowcharts and / or block diagrams are implemented. The program code may 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.

[0121] In the context of this application, a machine-readable medium can be a tangible medium that may contain or store a program for use by or in conjunction with an instruction execution system, apparatus, or device. A machine-readable medium can be a machine-readable signal medium or a machine-readable storage medium. Machine-readable media can be, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination of the foregoing. 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 of the foregoing.

[0122] To provide interaction with a user, the systems and techniques described herein can be implemented on a computer having: a display device for displaying information to the user (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor); and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the computer. 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).

[0123] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as a data server), or computing systems that include middleware components (e.g., an application server), or computing systems that include frontend components (e.g., a user computer with a graphical user interface or web browser through which a user 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., a communication network). Examples of communication networks include local area networks (LANs), wide area networks (WANs), and the Internet.

[0124] Computer systems can include clients and servers. Clients and servers are generally located far apart and typically interact via communication networks. Client-server relationships are created by computer programs running on the respective computers and having a client-server relationship with each other. Servers can be cloud servers, servers in distributed systems, or servers incorporating blockchain technology.

[0125] It should be understood that the various forms of processes shown above can be used to rearrange, add, or delete steps. For example, the steps described in this application can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution disclosed in this application can be achieved, and this is not limited herein.

[0126] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

Claims

1. A method for exploiting buried hill oil reservoirs, characterized in that, The method includes: The target buried hill reservoir is assessed for its reservoir characteristics, and a comprehensive assessment result is obtained. The comprehensive assessment result includes the structural characteristics assessment result, the reservoir heterogeneity assessment result, the reservoir energy assessment result, and the remaining oil distribution assessment result. Based on the comprehensive evaluation results, the structure of the three-dimensional well network corresponding to the target buried hill reservoir is configured to obtain the target three-dimensional well network; the target three-dimensional well network is used to collect data from the target buried hill reservoir; the three-dimensional well network includes gas injection wells, oil production wells, and water injection wells. The process of configuring the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation results to obtain the target three-dimensional well network includes: configuring the location and number of gas injection wells based on the structural feature evaluation results and the remaining oil distribution evaluation results to obtain target gas injection wells; configuring the vertical position of the wellbore perforations and the planar position of the production wells based on the reservoir energy evaluation results and the remaining oil distribution evaluation results to obtain target production wells; configuring the location and number of water injection wells based on the reservoir energy evaluation results and the reservoir heterogeneity evaluation results to obtain target water injection wells; and constructing the target three-dimensional well network based on the target gas injection wells, the target production wells, and the target water injection wells. In response to the reservoir energy assessment result indicating that the bottom water intensity is greater than a set first bottom water intensity threshold, the vertical position is configured at a first position corresponding to the oil column height of the production well; in response to the reservoir energy assessment result indicating that the bottom water intensity is less than a set second bottom water intensity threshold, the vertical position is configured at a second position corresponding to the oil column height of the production well; the first bottom water intensity threshold and the second bottom water intensity threshold may be the same as or different; the first position is lower than the second position; in response to the reservoir energy assessment result indicating that the edge water intensity is greater than a set first edge water intensity threshold, the planar positions of a first number of production wells are configured at a third position on the original oil-water interface, and the planar positions of a second number of production wells are configured at a fourth position on the original oil-water interface; the first number is greater than the second number, and the distance between the fourth position and the original oil-water interface is less than the distance between the third position and the original oil-water interface; in response to the reservoir energy assessment result indicating that the edge water intensity is less than a set second edge water intensity threshold, a row of injection wells is arranged along the original oil-water interface, the injection wells being used to generate edge water drive; the first edge water intensity threshold and the second edge water intensity threshold may be the same as or different. The target three-dimensional well network is monitored in real time to obtain the production data of the target three-dimensional well network, and the injection and production parameters of each well are adjusted based on the production data to obtain the target injection and production parameters; Based on the target injection and production parameters and the corresponding oil production technology of each well, the target buried hill oil reservoir is exploited using the target three-dimensional well network.

2. The method according to claim 1, characterized in that, The reservoir characteristic assessment of the target buried hill reservoir yields a comprehensive assessment result, including: The structural characteristics of the target buried hill reservoir are evaluated to obtain structural characteristic evaluation results; the structural characteristic evaluation results include structural morphology, fracture system and buried hill amplitude. The target buried hill reservoir is subjected to reservoir heterogeneity assessment to obtain reservoir heterogeneity assessment results; the reservoir heterogeneity assessment results include macroscopic reservoir parameters and microscopic fluid parameters; The target buried hill reservoir was subjected to reservoir energy assessment, and the reservoir energy assessment results were obtained; the reservoir energy assessment results included bottom water intensity and edge water intensity. The remaining oil distribution of the target buried hill reservoir is assessed to obtain the remaining oil distribution assessment results; the remaining oil distribution assessment results include the remaining oil enrichment area and the remaining oil reserves.

3. The method according to claim 1, characterized in that, The process involves real-time monitoring of the target three-dimensional well network to obtain its production data, and adjusting the injection and production parameters of each well based on this data to obtain the target injection and production parameters, including: The production data includes pressure data, production data, water cut data, and gas cut data corresponding to the target three-dimensional well network; the target three-dimensional well network includes target gas injection wells, target oil production wells, and target water injection wells; Based on the production data, the gas injection parameters of the target gas injection well, the oil production parameters of the target oil production well, and the water injection parameters of the target water injection well are dynamically adjusted to obtain the target injection-production parameters.

4. The method according to claim 1, characterized in that, The oil production process includes: profile control and water shut-off technology for the target gas injection well, lifting technology for the target oil production well, and water control measures for the target water injection well.

5. The method according to claim 3, characterized in that, The process of dynamically adjusting the gas injection parameters of the target gas injection well, the oil production parameters of the target oil production well, and the water injection parameters of the target water injection well based on the production data to obtain the target injection-production parameters includes: Based on the pressure data, the gas injection intensity of the target gas injection well is adjusted to obtain the target gas injection intensity; Based on the water cut data and the gas cut data, the oil production intensity of the target oil well is adjusted to obtain the target oil production intensity; Based on the production data, the water injection intensity of the target water injection well is adjusted to obtain the target water injection intensity; the water injection intensity, gas injection intensity, and oil production intensity are interrelated. The target injection and production parameters are determined based on the target gas injection intensity, the target oil production intensity, and the target water injection intensity.

6. A device for developing buried hill oil reservoirs, characterized in that, include: The evaluation module is used to evaluate the reservoir characteristics of the target buried hill reservoir and obtain a comprehensive evaluation result. The comprehensive evaluation result includes the structural characteristic evaluation result, the reservoir heterogeneity evaluation result, the reservoir energy evaluation result, and the remaining oil distribution evaluation result. The configuration module is used to configure the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation results, so as to obtain the target three-dimensional well network; The target three-dimensional well network is used to collect data from the target buried hill oil reservoir; The three-dimensional well network includes gas injection wells, oil production wells, and water injection wells; The process of configuring the structure of the three-dimensional well network corresponding to the target buried hill reservoir based on the comprehensive evaluation results to obtain the target three-dimensional well network includes: configuring the location and number of gas injection wells based on the structural feature evaluation results and the remaining oil distribution evaluation results to obtain target gas injection wells; configuring the vertical position of the wellbore perforations and the planar position of the production wells based on the reservoir energy evaluation results and the remaining oil distribution evaluation results to obtain target production wells; configuring the location and number of water injection wells based on the reservoir energy evaluation results and the reservoir heterogeneity evaluation results to obtain target water injection wells; and constructing the target three-dimensional well network based on the target gas injection wells, the target production wells, and the target water injection wells. In response to the reservoir energy assessment result indicating that the bottom water intensity is greater than a set first bottom water intensity threshold, the vertical position is configured at a first position corresponding to the oil column height of the production well; in response to the reservoir energy assessment result indicating that the bottom water intensity is less than a set second bottom water intensity threshold, the vertical position is configured at a second position corresponding to the oil column height of the production well; the first bottom water intensity threshold and the second bottom water intensity threshold may be the same as or different; the first position is lower than the second position; in response to the reservoir energy assessment result indicating that the edge water intensity is greater than a set first edge water intensity threshold, the planar positions of a first number of production wells are configured at a third position on the original oil-water interface, and the planar positions of a second number of production wells are configured at a fourth position on the original oil-water interface; the first number is greater than the second number, and the distance between the fourth position and the original oil-water interface is less than the distance between the third position and the original oil-water interface; in response to the reservoir energy assessment result indicating that the edge water intensity is less than a set second edge water intensity threshold, a row of injection wells is arranged along the original oil-water interface, the injection wells being used to generate edge water drive; the first edge water intensity threshold and the second edge water intensity threshold may be the same as or different. The adjustment module is used to monitor the target three-dimensional well network in real time, obtain the production data of the target three-dimensional well network, and adjust the injection and production parameters of each well based on the production data to obtain the target injection and production parameters. The extraction module is used to extract the target buried hill oil reservoir based on the target injection and production parameters and the corresponding oil production technology of each well, using the target three-dimensional well network.

7. An electronic device, characterized in that, include: At least one processor; as well as A memory communicatively connected to the at least one processor; wherein, The memory stores instructions that can be executed by the at least one processor to enable the at least one processor to perform the method of any one of claims 1-5.

8. A non-transitory computer-readable storage medium storing computer instructions, characterized in that, The computer instructions are used to cause the computer to perform the method according to any one of claims 1-5.

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