An oil production process index benchmarking method, system and device

Abstract

This invention belongs to the field of oil extraction, specifically relating to a method, system, and equipment for benchmarking oil production process indicators. It aims to address the shortcomings of existing technologies in establishing a comprehensive, systematic, and advanced benchmarking system for mechanical oil production process indicators, particularly in the overall representation of economic indicators, the correlation between technology and economics, and the availability of applicable benchmarking methods. The invention includes: acquiring the technical and economic indicators of mechanical oil production; classifying existing oil reservoirs into loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs; obtaining the average values ​​of each indicator participating in the benchmarking within a set range for different types of reservoirs; and comparing the average values ​​with benchmark values ​​to obtain the benchmarking results. This invention optimizes the mechanical oil production process through systematic benchmarking analysis technology and economic indicators, improving the scientific nature of decision-making, production efficiency, and resource utilization, while reducing costs and enhancing environmental protection.

Description

Technical Field

[0001] This invention belongs to the field of oil extraction, and specifically relates to a method, system and equipment for benchmarking oil extraction process indicators. Background Technology

[0002] Mechanical oil recovery process benchmarking refers to the comparative analysis of technical and economic indicators in various processes of oil recovery using mechanical equipment in the oil extraction industry. This process typically aims to evaluate key indicators such as efficiency, cost-effectiveness, energy consumption, and environmental impact among different oilfields or different oil recovery methods, thereby optimizing production processes, improving resource utilization, reducing operating costs, ensuring safe production, and minimizing environmental impact.

[0003] In the prior art, patent application number 202311519626.9, entitled "An Optimization Method for Pumping Unit Well Parameters Based on Neural Networks," discloses the establishment of a sample database based on a large amount of production data from oilfield blocks. It utilizes clustering algorithms to mine and analyze the sample database, selecting high-efficiency wells as the superior sample set in the database using downhole efficiency as an evaluation index. Based on similar production volume and flowing pressure, oil wells with different formation fluid supply capabilities are classified. Using data samples from each well group after classification, a downhole efficiency prediction model is established in conjunction with a neural network. The optimized variable parameters of high-efficiency wells in the superior sample set are referenced to scientifically and effectively guide field production. However, this patent only establishes a sample database, classifies oil wells, and performs cluster analysis on the single indicator of downhole efficiency. It does not establish a benchmarking system for mechanical oil recovery technology indicators, resulting in insufficient overall economic indicators, weak technical-economic correlation, and a lack of a comprehensive, systematic, and advanced benchmarking system and method for mechanical oil recovery technology.

[0004] The invention patent application number 201810781263.9, entitled "An Invention Patent for a New Energy Industry Benchmarking System Based on Comprehensive Evaluation," discloses the establishment of a weighted grey comprehensive evaluation model combining subjective and objective weighting, and compares and analyzes the evaluation results of the combined model with other evaluation methods. Based on user needs, the functional requirements of the new energy industry benchmarking platform, the functional requirements of the back-end management system, and other non-functional requirements, the overall architecture and main functional modules of the new energy industry benchmarking system are designed, inheriting the combined evaluation model and providing important support for better new energy industry benchmarking. Although a weighted grey comprehensive evaluation model combining subjective and objective weighting has been formed, a benchmarking method applicable to mechanical oil recovery process indicators has not yet been developed.

[0005] Based on this, the present invention proposes a method, system and equipment for benchmarking oil production process indicators. Summary of the Invention

[0006] To address the aforementioned problems in the prior art, namely the failure of the prior art to establish a comprehensive, systematic, and advanced benchmarking system for mechanical oil recovery process indicators, particularly in terms of the overall representation of economic indicators, the correlation between technology and economics, and the lack of benchmarking methods applicable to mechanical oil recovery process indicators, this invention provides a method, system, and equipment for benchmarking oil recovery process indicators.

[0007] In a first aspect, this invention proposes a method for benchmarking oil recovery process indicators, the method comprising:

[0008] The technical and economic indicators of mechanical oil recovery are obtained. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days.

[0009] Existing reservoirs are classified based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs.

[0010] The average value of each indicator used for benchmarking in different types of reservoirs is obtained within a set range. The average value is then compared with the benchmark value to obtain the benchmarking result.

[0011] In some preferred embodiments, the plurality of wells includes at least pumping unit wells and submersible plunger pump wells, screw pump wells and submersible screw pump wells, and submersible centrifugal pump single wells.

[0012] In some preferred embodiments, the pump efficiency is calculated as follows:

[0013] Pump efficiency = (actual displacement / theoretical displacement) × 100%;

[0014] Wherein, the actual discharge = daily water production + ((1-water cut) × daily liquid production ρ), where ρ is the density of crude oil.

[0015] In some preferred embodiments, wells participating in the benchmarking are selected based on pump efficiency and production days, using the following method:

[0016] The number of production days of pumping unit wells and submersible plunger pump single wells is greater than or equal to the preset threshold, and the pump efficiency is included in the benchmark within the first interval;

[0017] The production days of screw pump wells and submersible screw pump wells are greater than or equal to the preset threshold, and the pump efficiency is included in the benchmarking within the second interval.

[0018] The number of production days of a single well using a submersible centrifugal pump is greater than or equal to a preset threshold, and the pump efficiency is within the third interval for benchmarking.

[0019] In some preferred embodiments, the pump inspection cycle is the actual number of production days between the two most recent pump inspection operations of the oil well.

[0020] In some preferred embodiments, existing reservoirs are classified using the following methods:

[0021] Oil reservoirs with porosity greater than the first preset value and permeability greater than the second preset value are classified as loose sandstone oil reservoirs.

[0022] Oil reservoirs with crude oil viscosity greater than the third preset value and crude oil relative density greater than the fourth preset value are classified as heavy oil reservoirs.

[0023] Oil reservoirs with a burial depth greater than the fifth preset value and a permeability less than the sixth preset value are classified as deep low-permeability oil reservoirs.

[0024] Oil reservoirs whose comprehensive water cut exceeds the seventh preset value after the oilfield development period is defined as ultra-high water-cut oil reservoirs.

[0025] In some preferred embodiments, the system efficiency is calculated as follows:

[0026] System efficiency = Active power / Power consumed;

[0027] Wherein, active power = (oil well production × effective head × mixture density × gravitational acceleration) / b, where b is the second preset coefficient;

[0028] Effective head = dynamic liquid surface + (oil pressure - casing pressure) × c / (mixture density × gravitational acceleration), where c is the third preset coefficient;

[0029] The density of the mixture = (1 - water content) × oil density + water content × water density.

[0030] In another aspect, the present invention proposes an oil production process index benchmarking system, based on an oil production process index benchmarking method, the system comprising:

[0031] The indicator acquisition module is configured to acquire technical and economic indicators of mechanical oil recovery. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days.

[0032] The reservoir classification module is configured to classify existing reservoirs based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs.

[0033] The benchmarking module is configured to obtain the average value of each indicator participating in the benchmarking in different types of reservoirs within a set range, and compare the average value with the benchmark value to obtain the benchmarking result.

[0034] A third aspect of the present invention provides an electronic device comprising:

[0035] At least one processor; and

[0036] A memory communicatively connected to at least one of the processors; wherein,

[0037] The memory stores instructions that can be executed by the processor to implement the above-described method for benchmarking oil production process indicators.

[0038] In a fourth aspect, the present invention provides a computer-readable storage medium storing computer instructions for execution by a computer to implement the above-described method for benchmarking oil production process indicators.

[0039] The beneficial effects of this invention are:

[0040] Improving the scientific rigor and accuracy of decision-making: Through systematic benchmarking analysis of technical and economic indicators in mechanical oil extraction, best practices under different reservoir conditions can be identified more accurately, providing decision-makers with a scientific basis and improving the quality of decision-making.

[0041] Optimize production processes: By comparing the oil production efficiency and techno-economic indicators under different reservoir types, bottlenecks in the production process can be identified, and measures can then be taken to optimize the production process and improve resource utilization.

[0042] Cost reduction: Through benchmarking analysis, production costs can be effectively identified and controlled, and operating costs can be reduced by improving technical means and management measures.

[0043] Improving environmental protection: This invention takes into account the important indicator of environmental impact, and reduces the negative impact on the environment while optimizing production, which helps to achieve green mining.

[0044] Enhancing the Technological and Economic Linkage: This invention not only focuses on technical indicators but also emphasizes the performance of economic indicators, establishing a link between the two, which helps to more comprehensively evaluate the overall benefits of oil production projects. Attached Figure Description

[0045] Other features, objects, and advantages of this application will become more apparent from the following detailed description of non-limiting embodiments with reference to the accompanying drawings:

[0046] Figure 1 This is a flowchart illustrating a method for benchmarking oil production process indicators according to the present invention.

[0047] Figure 2 This is a schematic diagram of the structure of a computer system used to implement the methods, systems, and devices of this application. Detailed Implementation

[0048] The present application will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are for illustrative purposes only and are not intended to limit the invention. Furthermore, it should be noted that, for ease of description, only the parts relevant to the invention are shown in the accompanying drawings.

[0049] It should be noted that, unless otherwise specified, the embodiments and features described in this application can be combined with each other. This application will now be described in detail with reference to the accompanying drawings and embodiments.

[0050] The first embodiment of the present invention provides a method for benchmarking oil production process indicators, the method comprising:

[0051] The technical and economic indicators of mechanical oil recovery are obtained. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days.

[0052] Existing reservoirs are classified based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs.

[0053] The average value of each indicator used for benchmarking in different types of reservoirs is obtained within a set range. The average value is then compared with the benchmark value to obtain the benchmarking result.

[0054] To more clearly explain the oil recovery process index benchmarking method of the present invention, the following is in conjunction with... Figure 1 The embodiments of the present invention will be described in detail below:

[0055] The technical and economic indicators of mechanical oil recovery are obtained. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days.

[0056] In this embodiment, the multiple wells include at least pumping unit wells and submersible plunger pump wells, screw pump wells and submersible screw pump wells, and submersible centrifugal pump single wells.

[0057] The pump efficiency is calculated as follows:

[0058] Pump efficiency = (actual displacement / theoretical displacement) × 100%;

[0059] Wherein, the actual discharge = daily water production + ((1-water content) × daily liquid production ρ), where ρ is the density of crude oil, preferably 0.86 in this embodiment.

[0060] The theoretical displacement of pumping unit wells and submersible plunger pump wells is calculated as follows: 1440 × π / 4 × pump diameter × pump diameter × stroke × number of strokes × 10 -6 ;

[0061] Theoretical displacement of screw pump wells and submersible screw pump wells = 1440 × rotational speed × pump displacement per revolution × 10 -6 ;

[0062] The theoretical displacement of a single well for a submersible centrifugal pump equals the nameplate displacement.

[0063] In this embodiment, wells participating in the benchmarking are selected based on pump efficiency and production days, and the method is as follows:

[0064] The number of production days of pumping unit wells and submersible plunger pump single wells is greater than or equal to the preset threshold, and the pump efficiency is included in the benchmark within the first interval;

[0065] The production days of screw pump wells and submersible screw pump single wells are greater than or equal to the preset threshold, and the pump efficiency is benchmarked within the second interval;

[0066] The number of production days of a single well using a submersible centrifugal pump is greater than or equal to a preset threshold, and the pump efficiency is within the third interval for benchmarking.

[0067] In this embodiment, the preset threshold is preferably 1, the first interval is preferably [20%, 80%], the second interval is preferably [20%, 100%], and the third interval is preferably [20%, 150%].

[0068] Specifically, pumping unit wells and submersible plunger pump wells with a production day count >= 1 and a pump efficiency of 20% <= 80% are included in the statistics;

[0069] Screw pump wells and submersible screw pump wells with a production day count >= 1 and a pump efficiency of 20% <= 100% are included in the statistics;

[0070] Submersible centrifugal pumps are included in the statistics if the number of production days per well is greater than or equal to 1 and the pump efficiency is less than or equal to 20% and less than or equal to 150%.

[0071] In this invention, the pump inspection cycle refers to the actual number of production days between the two most recent pump inspection operations of the oil well. The specific calculation method is as follows:

[0072] ① For wells that have stopped production due to subjective or objective reasons and have not been repaired in time, the date of the stoppage of production shall be the end date of this cycle;

[0073] ② For wells that have not produced oil and for which pump maintenance has not been carried out in a timely manner, the date on which oil production ceases to be produced shall be the end date of this cycle;

[0074] ③ The pump inspection cycle for intermittent pumping wells is calculated based on the actual number of days the well is in operation, with the number of days the well is shut down for the entire day deducted;

[0075] ④ Method for calculating the pump inspection cycle of wells that continue normal production from the start of pumping and wells that switch from flowing to pumping as of the date of statistics: If the number of consecutive production days from the start of pumping to the date of statistics is greater than the average pump inspection cycle of the unit or the block, then the number of consecutive production days is the pump inspection cycle of the well; if the number of consecutive production days is less than the average pump inspection cycle of the unit or the block, then the well is not included in the statistics.

[0076] ⑤ For wells that have already undergone pump inspection, if they continue production as of the statistical date, the method for calculating the pump inspection cycle is as follows:

[0077] As of the statistical date, if the number of consecutive production days is greater than the previous pump inspection cycle, then that number of consecutive production days is considered the pump inspection cycle for that well. Conversely, if the current consecutive production days are less than the previous pump inspection cycle, then the previous pump inspection cycle is considered the pump inspection cycle for that well. For any measures such as fracturing, acidizing, sand control, water plugging, pump replacement, perforation modification, and dynamic tubing pressure testing, if the current production days as of the date of the measure are greater than the previous pump inspection cycle for that well, then the current production days are considered the pump inspection cycle for that well; if the current production days are less than the previous pump inspection cycle, then the previous pump inspection cycle is considered the pump inspection cycle for that well. The date of resumption of pumping after the measure marks the start of the next pump inspection cycle. Pump inspection and replacement are carried out simultaneously with the measure operations, and statistics are based on pump inspections.

[0078] The calculation method for the aforementioned economic indicators is as follows:

[0079] The system efficiency is calculated as follows:

[0080] System efficiency = Active power / Power consumed;

[0081] Wherein, active power = (oil well production × effective head × mixture density × gravitational acceleration) / b, where b is the second preset coefficient;

[0082] Among them, b is preferably 86400.

[0083] Effective head = dynamic liquid surface + (oil pressure - casing pressure) × c / (mixture density × gravitational acceleration), where c is the third preset coefficient;

[0084] Where c is preferably 1000.

[0085] The density of the mixture = (1 - water content) × oil density + water content × water density.

[0086] Input power = Daily power consumption / 24.

[0087] Existing reservoirs are classified based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs.

[0088] Specifically: oil reservoirs with porosity greater than the first preset value and permeability greater than the second preset value are classified as loose sandstone oil reservoirs;

[0089] In this embodiment, the first preset value is preferably 25%, and the second preset value is preferably 500×10. -3 μm 2 In other words, loose sandstone reservoirs have weak rock cementation, loose intergranular contact, porosity greater than 25%, and permeability greater than 500 × 10⁻⁶. -3 μm 2 Oil reservoirs of this type are prone to sand production problems during development. This means that sand particles in the formation enter the wellbore along with the fluid flow, affecting the normal production of the oil well and even leading to more serious problems such as wellbore collapse and casing deformation.

[0090] Oil reservoirs with crude oil viscosity greater than the third preset value and crude oil relative density greater than the fourth preset value are classified as heavy oil reservoirs.

[0091] In this embodiment, the third preset value is preferably 50 mPa·s, and the fourth preset value is preferably 0.92.

[0092] Oil reservoirs with a burial depth greater than the fifth preset value and a permeability less than the sixth preset value are classified as deep low-permeability oil reservoirs.

[0093] In this embodiment, the fifth preset value is preferably 3000m, and the sixth preset value is preferably 50×10. -3 μm 2 .

[0094] Oil reservoirs whose comprehensive water cut exceeds the seventh preset value after the oilfield development period is defined as ultra-high water-cut oil reservoirs.

[0095] In this embodiment, the seventh preset value is preferably 90%. In this embodiment, the oilfield development time setting specifically refers to the later stage of oilfield development. The specific time is determined by those skilled in the art based on the situation of different oilfields.

[0096] The average value of each indicator used for benchmarking in different types of reservoirs is obtained within a set range. The average value is then compared with the benchmark value to obtain the benchmarking result.

[0097] The set range is 40%-60%. Specifically, the average value is the average of the mechanical production indicators of wells of different reservoir types within the 40%-60% range.

[0098] The benchmark value is the average of the values ​​of each mechanical production index of wells of different reservoir types that are better than the values ​​of more than 80% of wells.

[0099] This invention analyzes benchmark results to determine the reasons why indicators are lower than benchmark values ​​and provides experience regarding indicators that are higher than benchmark values. Specifically, it analyzes the reasons why mechanical oil recovery indicators for different reservoir types are lower than the average value:

[0100] We analyzed why the well was below average and implemented targeted optimizations.

[0101] Summary of experience on wells with mechanical recovery indicators higher than benchmark values ​​for different reservoir types:

[0102] The successful experience of this well exceeding the benchmark value should be summarized and applied to other wells of this reservoir type.

[0103] Based on the above, the present invention has conducted specific experiments, the details of which are as follows:

[0104] Select a mechanically operated oil well, X34-13, for benchmarking against the oil production indicators to be developed.

[0105] 1. Determine the technical parameters of mechanical oil recovery.

[0106] (1) Technical indicators

[0107] Pump efficiency = (Actual displacement / Theoretical displacement) * 100% = 10.81 / 34.2 = 31.6%

[0108] Pump inspection cycle = Single well pump inspection cycle refers to the actual number of production days between the two most recent pump inspection operations of the oil well = 409 days

[0109] Economic indicators

[0110] System efficiency = Active power / Power consumed = 21.76%

[0111] 2. Determine reservoir classification

[0112] The reservoir to which this well belongs has an average porosity of 31% and an average permeability of 710 × 10⁻⁶. -3 μm 2 The rock has weak cementation and the particles are not tightly connected, making it a loose sandstone oil reservoir.

[0113] 3. Determine the average and benchmark values ​​of mechanical oil recovery technology parameters for different reservoir types.

[0114] (1) Average value: The average value of each mechanical production index of the well in this reservoir type is within the range of 40%-60%.

[0115] Average pump efficiency = 58.18%;

[0116] The average pump inspection cycle is 974 days.

[0117] The average system efficiency is 30.33%.

[0118] (2) Benchmark value: The average value of each mechanical production index of wells of this reservoir type that is better than the average value of more than 80% of wells.

[0119] Pump efficiency benchmark value = 75.6%;

[0120] The benchmark value for pump inspection cycle is 2508 days.

[0121] System efficiency benchmark value = 48.93%.

[0122] 4. Analysis of the reasons why the mechanical oil production index of this well is lower than the average value.

[0123] The analysis revealed that the pump efficiency of this well was below average because of its large pump diameter, and the pump was specifically optimized from φ57mm to φ44mm. The analysis also revealed that the pump inspection cycle was below average because of a valve cover quality issue, and the system was specifically optimized by replacing it with a stainless steel closed valve cover. Finally, the analysis revealed that the system efficiency was below average because the control cabinet was a static frequency control cabinet, and the system was specifically optimized by replacing it with an energy-saving variable frequency control cabinet.

[0124] 5. The mechanical oil recovery index of this well is lower than the benchmark value, therefore no experience summary is required.

[0125] X34-13 uses this method to calculate pump efficiency, pump inspection cycle, and system efficiency index values, and compares them with the average index and benchmark index of loose sandstone reservoirs to find the reasons for wells that did not reach the average index and to carry out targeted optimization. After optimization, the overall average pump efficiency increased by 8.5 percentage points, the average pump inspection cycle was extended by 113 days, and the average system efficiency increased by 1.35 percentage points.

[0126] Although the steps in the above embodiments are described in the above order, those skilled in the art will understand that in order to achieve the effect of this embodiment, different steps do not need to be executed in such an order. They can be executed simultaneously (in parallel) or in a reverse order. These simple variations are all within the protection scope of this invention.

[0127] A second embodiment of the present invention provides an oil production process indicator benchmarking system, based on an oil production process indicator benchmarking method. The system includes:

[0128] The indicator acquisition module is configured to acquire technical and economic indicators of mechanical oil recovery. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days.

[0129] The reservoir classification module is configured to classify existing reservoirs based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs.

[0130] The benchmarking module is configured to obtain the average value of each indicator participating in the benchmarking in different types of reservoirs within a set range, and compare the average value with the benchmark value to obtain the benchmarking result.

[0131] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the system described above can be found in the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0132] It should be noted that the oilfield process indicator benchmarking system provided in the above embodiments is only an example of the division of the above functional modules. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the modules or steps in the embodiments of the present invention can be further decomposed or combined. For example, the modules in the above embodiments can be merged into one module, or further divided into multiple sub-modules to complete all or part of the functions described above. The names of the modules and steps involved in the embodiments of the present invention are only for distinguishing the various modules or steps and are not considered as an improper limitation of the present invention.

[0133] An electronic device according to a third embodiment of the present invention includes:

[0134] At least one processor; and

[0135] A memory communicatively connected to at least one of the processors; wherein,

[0136] The memory stores instructions that can be executed by the processor to implement the above-described method for benchmarking oil production process indicators.

[0137] A computer-readable storage medium according to a fourth embodiment of the present invention stores computer instructions, which are executed by the computer to implement the above-described method for benchmarking oil production process indicators.

[0138] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the storage device and processing device described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0139] Those skilled in the art will recognize that the modules and method steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, computer software, or a combination of both. The programs corresponding to the software modules and method steps can be placed in random access memory (RAM), main memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disks, removable disks, CD-ROMs, or any other form of storage medium known in the art. To clearly illustrate the interchangeability of electronic hardware and software, the components and steps of the various examples have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in electronic hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of the invention.

[0140] The following is for reference. Figure 2 It shows a schematic diagram of the structure of a computer system for implementing the methods, systems, and devices of this application. Figure 2 The server shown is merely an example and should not impose any limitations on the functionality and scope of use of the embodiments of this application.

[0141] like Figure 2 As shown, the computer system includes a Central Processing Unit (CPU) 201, which can perform various appropriate actions and processes based on programs stored in Read Only Memory (ROM) 202 or programs loaded from storage section 208 into Random Access Memory (RAM) 203. The RAM 203 also stores various programs and data required for system operation. The CPU 201, ROM 202, and RAM 203 are interconnected via a bus 204. An Input / Output (I / O) interface 205 is also connected to the bus 204.

[0142] The following components are connected to I / O interface 205: an input section 206 including a keyboard, mouse, etc.; an output section 207 including a cathode ray tube (CRT), liquid crystal display (LCD), etc., and speakers, etc.; a storage section 208 including a hard disk, etc.; and a communication section 209 including a network interface card such as a LAN (Local Area Network) card, modem, etc. The communication section 209 performs communication processing via a network such as the Internet. A drive 210 is also connected to I / O interface 205 as needed. Removable media 211, such as a disk, optical disk, magneto-optical disk, semiconductor memory, etc., are installed on drive 210 as needed so that computer programs read from them can be installed into storage section 208 as needed.

[0143] Specifically, according to embodiments of this disclosure, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments of this disclosure include a computer program product comprising a computer program carried on a computer-readable medium, the computer program containing program code for performing the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via communication section 209, and / or installed from removable medium 211. When the computer program is executed by central processing unit (CPU) 201, it performs the functions defined in the methods of this application. It should be noted that the computer-readable medium described above in this application can be a computer-readable signal medium or a computer-readable storage medium, or any combination of the two. A computer-readable storage medium can be, for example,—but not limited to—an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples of computer-readable storage media may include, but are not limited to: electrical connections having 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 fiber, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In this application, a computer-readable storage medium can be any tangible medium containing or storing a program that can be used by or in connection with an instruction execution system, apparatus, or device. In this application, a computer-readable signal medium may include a data signal propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals can take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination thereof. A computer-readable signal medium can also be any computer-readable medium other than a computer-readable storage medium, which can send, propagate, or transmit a program for use by or in connection with an instruction execution system, apparatus, or device. The program code contained on a computer-readable medium can be transmitted using any suitable medium, including but not limited to: wireless, wire, optical fiber, RF, etc., or any suitable combination thereof.

[0144] Computer program code for performing the operations of this application can be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages ​​such as Java, Smalltalk, and C++, and conventional procedural programming languages ​​such as the "C" language or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0145] The flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of systems, methods, and computer program products according to various embodiments of this application. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions indicated in the blocks may occur in a different order than those indicated in the drawings. For example, two consecutively indicated blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in the block diagrams and / or flowcharts, and combinations of blocks in the block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or operation, or using a combination of dedicated hardware and computer instructions.

[0146] The terms “first”, “second”, etc., are used to distinguish similar objects, not to describe or indicate a specific order or sequence.

[0147] The term "comprising" or any other similar term is intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus / device that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent in such process, method, article, or apparatus / device.

[0148] The technical solution of the present invention has been described above with reference to the preferred embodiments shown in the accompanying drawings. However, it will be readily understood by those skilled in the art that the scope of protection of the present invention is obviously not limited to these specific embodiments. Without departing from the principles of the present invention, those skilled in the art can make equivalent changes or substitutions to the relevant technical features, and the technical solutions after these changes or substitutions will all fall within the scope of protection of the present invention.

Claims

1. A method for benchmarking oil recovery process parameters, characterized in that, The method includes: The technical and economic indicators of mechanical oil recovery are obtained. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days. Existing reservoirs are classified based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs. The average value of each indicator used for benchmarking in different types of reservoirs is obtained within a set range. The average value is then compared with the benchmark value to obtain the benchmarking result.

2. The method for benchmarking oil recovery process indicators according to claim 1, characterized in that, Multiple wells include at least pumping unit wells and submersible plunger pump wells, screw pump wells and submersible screw pump wells, and submersible centrifugal pump single wells.

3. The method for benchmarking oil recovery process indicators according to claim 1, characterized in that, The pump efficiency is calculated as follows: Pump efficiency = (actual displacement / theoretical displacement) × 100%; Wherein, the actual discharge = daily water production + ((1-water cut) × daily liquid production / ρ), where ρ is the density of crude oil.

4. The method for benchmarking oil recovery process indicators according to claim 2, characterized in that, Wells selected for benchmarking were determined based on pump efficiency and production days. The method used was as follows: The number of production days of pumping unit wells and submersible plunger pump single wells is greater than or equal to the preset threshold, and the pump efficiency is included in the benchmark within the first interval; The production days of screw pump wells and submersible screw pump wells are greater than or equal to the preset threshold, and the pump efficiency is included in the benchmarking within the second interval. The number of production days of a single well using a submersible centrifugal pump is greater than or equal to a preset threshold, and the pump efficiency is within the third interval for benchmarking.

5. The method for benchmarking oil recovery process indicators according to claim 1, characterized in that, The pump inspection cycle is the actual number of production days between the two most recent pump inspection operations of the oil well.

6. The method for benchmarking oil recovery process indicators according to claim 1, characterized in that, The method for classifying existing oil reservoirs is as follows: Oil reservoirs with porosity greater than the first preset value and permeability greater than the second preset value are classified as loose sandstone oil reservoirs. Oil reservoirs with crude oil viscosity greater than the third preset value and crude oil relative density greater than the fourth preset value are classified as heavy oil reservoirs. Oil reservoirs with a burial depth greater than the fifth preset value and a permeability less than the sixth preset value are classified as deep low-permeability oil reservoirs. Oil reservoirs whose comprehensive water cut exceeds the seventh preset value after the oilfield development period is defined as ultra-high water-cut oil reservoirs.

7. The method for benchmarking oil recovery process indicators according to claim 1, characterized in that, The system efficiency is calculated as follows: System efficiency = Active power / Power consumed; Wherein, active power = (oil well production × effective head × mixture density × gravitational acceleration) / b, where b is the second preset coefficient; Effective head = dynamic liquid surface + (oil pressure - casing pressure) × c / (mixture density × gravitational acceleration), where c is the third preset coefficient; The density of the mixture = (1 - water content) × oil density + water content × water density.

8. An oilfield process indicator benchmarking system, based on the oilfield process indicator benchmarking method according to any one of claims 1-7, characterized in that, The system includes: The indicator acquisition module is configured to acquire technical and economic indicators of mechanical oil recovery. The technical indicators include at least the pump efficiency and pump maintenance cycle of multiple wells, and the economic indicators include at least the system efficiency. Wells for benchmarking are selected based on pump efficiency and production days. The reservoir classification module is configured to classify existing reservoirs based on porosity, permeability, crude oil viscosity, reservoir depth, and water cut, resulting in loose sandstone reservoirs, heavy oil reservoirs, deep low-permeability reservoirs, and ultra-high water-cut reservoirs. The benchmarking module is configured to obtain the average value of each indicator participating in the benchmarking in different types of reservoirs within a set range, and compare the average value with the benchmark value to obtain the benchmarking result.

9. An electronic device, characterized in that, include: At least one processor; as well as A memory communicatively connected to at least one of the processors; wherein, The memory stores instructions that can be executed by the processor to implement the oil recovery process indicator benchmarking method according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that are executed by the computer to implement the oil recovery process indicator benchmarking method according to any one of claims 1-7.

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