Method for determining a time of driving under a two-three combination development mode and related equipment

Abstract

The application discloses a method for determining a conversion time of water flooding to chemical flooding in a two-three combination development mode and related equipment. The method comprises the following steps: constructing a first water flooding oil production rate function of a first well pattern and a second water flooding oil production rate function of a second well pattern respectively; constructing a chemical flooding oil production rate function of the second well pattern, wherein the chemical flooding oil production rate function is a chemical flooding oil production rate function of the second well pattern after m years of water flooding oil production, and m is the number of years of water flooding oil production of the second well pattern; performing economic benefit evaluation of a target oil field by using a comparison method according to the first water flooding oil production rate function, the second water flooding oil production rate function and the chemical flooding oil production rate function; and determining a conversion time of water flooding to chemical flooding of the second well pattern according to a result of the economic benefit evaluation. The method is based on oil production rate, and the best conversion time is determined by using an economic benefit evaluation method, so that the method is more simple and convenient for field application.

Description

Technical Field

[0001] This specification relates to the field of oil reservoir development, and more specifically, to a method and related equipment for determining the timing of switching to a two- or three-pronged development model. Background Technology

[0002] The "two-three combined development model" refers to a development stage where, with the opening of a new well network, both waterflooding and chemical flooding can be used for oil production. Chemical flooding technology has been promoted nationwide, but achieving profitable development under low oil prices faces significant challenges. Balancing production and profitability is difficult, and currently, there is no suitable method for determining the appropriate time to switch oilfield development from waterflooding to chemical flooding. Summary of the Invention

[0003] The summary section introduces a series of simplified concepts, which will be further explained in detail in the detailed description section. The summary section of this invention is not intended to limit the key features and essential technical features of the claimed technical solution, nor is it intended to determine the scope of protection of the claimed technical solution.

[0004] To improve the economic efficiency of oilfield development, firstly, this invention proposes a method for determining the timing of transition drive in a combined two- and three-stage development model, the method comprising:

[0005] The first water-drive oil production rate function of the first well network and the second water-drive oil production rate function of the second well network are constructed respectively. The first well network is the well network drilled under the first development mode, and the second well network is the well network drilled under the combined second and third development mode.

[0006] Construct the chemical flooding oil recovery rate function of the second well network mentioned above, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years that the second well network has adopted water flooding oil recovery.

[0007] Based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function and the chemical flooding oil recovery rate function, the economic benefits of the target oilfield are evaluated using the presence or absence comparison method.

[0008] Based on the results of the above economic benefit evaluation, the timing for converting the second well network from water-driven to chemical-driven was determined.

[0009] Optionally, the above-mentioned construction of the first waterdrive oil production rate function for the first well pattern and the second waterdrive oil production rate function for the second well pattern includes:

[0010] Based on historical production data, a first water-drive oil production rate function for the first well network and a second water-drive oil production rate function for the second well network are constructed. The first and second water-drive oil production rate functions are in exponential form.

[0011] Optionally, the chemical flooding production rate function for constructing the second well network includes:

[0012] The above chemical flooding oil production rate function is constructed based on the second water-drive oil production rate and the chemical flooding enhancement rate in the second well network.

[0013] Optionally, the above method also includes:

[0014] The rate of improvement of the chemical flooding was determined by numerical simulation, wherein the numerical simulation method includes Eclipse simulation or Cmg simulation.

[0015] Optionally, the above-mentioned economic benefit evaluation of the target oilfield using the presence-or-absence comparison method based on the first waterflooding oil recovery rate function, the second waterflooding oil recovery rate function, and the above-mentioned chemical flooding oil recovery rate function includes:

[0016] Based on the first water-drive oil production rate function, the second water-drive oil production rate function, and the chemical flooding oil production rate, the annual oil production rate of the target oilfield corresponding to different conversion schemes is determined. Among them, the water-drive oil production life m of the second well network corresponding to the different conversion schemes is different.

[0017] The economic benefits of different drive schemes are evaluated based on the annual oil production rate of the target oilfield.

[0018] Optionally, the above-mentioned economic benefit evaluation of different rotary displacement schemes based on the annual oil production rate of the target oilfield includes...

[0019] Calculate the annual sales revenue for each drive scheme based on the above annual oil production rate, geological reserves, and average annual oil price.

[0020] Calculate the total annual expenditure for each drive scheme based on the annual investment amount, annual working capital, and annual total cost.

[0021] Calculate the annual cash flow for each transformation scheme based on the above-mentioned annual sales revenue and total annual expenditure;

[0022] Based on the above cash flows, the internal rate of return under each transition scheme is determined using the IRR function;

[0023] The aforementioned internal rate of return is used in the aforementioned economic benefit evaluation;

[0024] The timing for converting the second well network from waterflooding to chemical flooding, determined based on the above economic benefit evaluation results, includes:

[0025] The conversion scheme corresponding to the maximum internal rate of return is determined as the timing for the conversion of the second well pattern from water flooding to chemical flooding.

[0026] Optionally, the above methods also include:

[0027] The total annual cost is calculated based on annual operating costs, annual chemical reagent costs, total period expenses, and annual taxes.

[0028] Secondly, the present invention also proposes a device for determining the timing of a transition drive in a two- or three-way combined development mode, comprising:

[0029] The first construction unit is used to construct the first water-drive oil production rate function of the first well network and the second water-drive oil production rate function of the second well network, wherein the first well network is the well network drilled under the first development mode and the second well network is the well network drilled under the combined two and three development mode.

[0030] The second building unit is used to build the chemical flooding oil recovery rate function of the second well network, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years that the second well network has adopted water flooding oil recovery.

[0031] The evaluation unit is used to evaluate the economic benefits of the target oilfield by using a comparison method based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function and the chemical flooding oil recovery rate function.

[0032] The determination unit is used to determine the timing of the conversion of the second well network from water drive to chemical drive based on the results of the above economic benefit evaluation.

[0033] Thirdly, an electronic device includes: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program stored in the memory to implement the method for determining the timing of a drive under a two- or three-way combined development mode as described in any of the first aspects above.

[0034] Fourthly, the present invention also proposes a computer-readable storage medium having a computer program stored thereon, wherein when the computer program is executed by a processor, it implements the method for determining the timing of the drive in the two-three combined development mode of any one of the preceding claims of the first aspect.

[0035] In summary, the method for determining the timing of conversion to chemical flooding under a combined two- and three-stage development model proposed in this application includes: constructing a first water-drive oil production rate function for a first well network and a second water-drive oil production rate function for a second well network, wherein the first well network is a well network drilled under the first development model, and the second well network is a well network drilled under the combined two- and three-stage development model; constructing a chemical flooding oil production rate function for the second well network, wherein the chemical flooding oil production rate function is the chemical flooding oil production rate function of the second well network after m years of water-drive oil production, where m is the number of years the second well network has used water-drive oil production; evaluating the economic benefits of the target oilfield using a comparison method based on the first water-drive oil production rate function, the second water-drive oil production rate function, and the chemical flooding oil production rate function; and determining the timing of the conversion of the second well network from water-drive to chemical flooding based on the results of the economic benefit evaluation. This application's embodiments obtain the first waterflooding oil production rate of the first well network, the second waterflooding oil production rate of the second well network, and the chemical flooding oil production rate. By combining these three oil production rates, the economic benefits of exploiting the target oilfield are evaluated, and the optimal timing for switching to the combined two- and three-stage oilfield exploitation model is determined by selecting the conversion scheme with the best economic benefits. This method, based on oil production rates and employing an economic benefit evaluation method to determine the optimal conversion timing, is simpler and more convenient for field application.

[0036] The method for determining the timing of the transition drive under the two- or three-way combined development mode of the present invention, other advantages, objectives and features of the present invention will be partly apparent from the following description, and partly understood by those skilled in the art through study and practice of the present invention. Attached Figure Description

[0037] Various other advantages and benefits will become apparent to those skilled in the art upon reading the following detailed description of preferred embodiments. The accompanying drawings are for illustrative purposes only and are not intended to limit this specification. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0038] Figure 1 A schematic flowchart illustrating a method for determining the timing of a transition drive under a two- or three-way combined development model, as provided in this application embodiment;

[0039] Figure 2 This is a schematic diagram illustrating the oil recovery rate under different drive schemes provided in an embodiment of this application;

[0040] Figure 3 This application provides an illustration of the economic benefits under different oil prices as part of its embodiments.

[0041] Figure 4 This application provides a device for determining the timing of a drive in a two- or three-way combined development model.

[0042] Figure 5 This is a schematic diagram of an electronic device structure for determining the timing of a drive under a two- or three-way combined development model, as provided in an embodiment of this application. Detailed Implementation

[0043] This application's embodiments obtain the first waterflooding oil production rate of the first well network, the second waterflooding oil production rate of the second well network, and the chemical flooding oil production rate. By combining these three oil production rates, the economic benefits of exploiting the target oilfield are evaluated, and the optimal timing for switching to the combined two- and three-stage oilfield exploitation model is determined by selecting the conversion scheme with the best economic benefits. This method, based on oil production rates and employing an economic benefit evaluation method to determine the optimal conversion timing, is simpler and more convenient for field application.

[0044] The terms "first," "second," "third," "fourth," etc. (if present) in the specification, claims, and accompanying drawings of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus. The technical solutions of the embodiments of this application will now be clearly and completely described in conjunction with the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, and not all of them.

[0045] Please see Figure 1 This is a flowchart illustrating a method for determining the timing of a transition drive under a two- or three-way combined development model, as described in an embodiment of this application. The method includes:

[0046] S110. Construct the first water-drive oil production rate function of the first well network and the second water-drive oil production rate function of the second well network respectively. The first well network is the well network opened under the first development mode, and the second well network is the well network opened under the combined second and third development mode.

[0047] For example, the first well network refers to the old well network drilled under the first development mode, which is always a water-drive production mode. The second well network is a newly drilled well network, which can be developed using either water-drive or chemical-drive methods. Both the first and second well networks are located in the same oilfield being developed. The second development mode refers to the water-drive production mode of the second well network, and the third development mode refers to the chemical-drive production mode of the second well network. The first water-drive oil recovery rate function is the function corresponding to the water-drive oil recovery rate in the first well network and the production year of the first well network. The second water-drive oil recovery rate function is the function corresponding to the water-drive oil recovery rate after the second well network is drilled and the production year of the second well network. It should be noted that the calculation of the first and second water-drive oil recovery rate functions can be stopped once the water-drive oil recovery rate is predicted. The predicted water-drive oil recovery rate is the oil recovery rate at which the oilfield is considered to have no need for further development under this predicted water-drive oil recovery rate.

[0048] S120. Construct the chemical flooding oil recovery rate function of the second well network mentioned above, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years that the second well network has adopted water flooding oil recovery.

[0049] For example, suppose the second well network switches to chemical flooding after m years of waterflooding. Obtain the oil production rate function for the following n years with different values ​​of m. Based on the chemical flooding oil production rate function, the annual production rate of the second well network after adopting chemical flooding can be obtained.

[0050] S130. Based on the above-mentioned first water-drive oil recovery rate function, second water-drive oil recovery rate function and above-mentioned chemical flooding oil recovery rate function, the economic benefits of the target oilfield are evaluated using the presence or absence comparison method.

[0051] For example, based on the first waterflooding oil recovery rate function, the second waterflooding oil recovery rate function, and the chemical flooding oil recovery rate function obtained in steps S110 and S120, the economic benefits of the target oilfield development under different m-values ​​are evaluated.

[0052] S140. Based on the results of the above economic benefit evaluation, determine the timing for the conversion of the second well network from water drive to chemical drive.

[0053] For example, based on the economic benefit evaluation results of the different m values ​​calculated in step S130, the conversion scheme with the best economic benefit is selected. The m value corresponding to the conversion scheme with the highest economic benefit is the conversion timing of the second well network from water drive to chemical drive.

[0054] In summary, this application's embodiments obtain the first waterflood production rate of the first well network, the second waterflood production rate of the second well network, and the chemical flooding production rate. By combining these three production rates, the economic benefits of exploiting the target oilfield are evaluated, and the optimal conversion timing under the combined two- and three-stage production model is determined by selecting the conversion scheme with the best economic benefits. This method, based on production rates and employing an economic benefit evaluation method to determine the optimal conversion timing, is simpler and more convenient for field application.

[0055] In some examples, the above-described construction of the first waterdrive production rate function for the first well pattern and the second waterdrive production rate function for the second well pattern includes:

[0056] Based on historical production data, a first water-drive oil production rate function for the first well network and a second water-drive oil production rate function for the second well network are constructed. The first and second water-drive oil production rate functions are in exponential form.

[0057] For example, by combining historical production data, water drive decline rate prediction curves for the first and second well networks are established, the starting point production rate of the first and second well networks is determined, and the water drive production rate for each year is predicted based on the decline rate.

[0058] Furthermore, the annual waterflood production rate V of the first well pattern can be calculated using equation (1). ji :

[0059] V ji =V j0 (1-b) (i-1) (1)

[0060] In the formula, V j0 denoted as b, where b is the water-drive oil production rate in the first year of production for the first well network, and i is the water-drive production time (in years).

[0061] The annual waterflood production rate V of the second well network can be calculated using equation (2). ji :

[0062] V xi =V x0 (1-a) (i-1) (2)

[0063] In the formula, V x0 denoted as , where is the water-drive oil production rate during the first year of production in the second well network; 'a' is the water-drive production deceleration rate of the second well network; and 'i' is the water-drive production time (in years).

[0064] In some examples, the chemical flooding production rate function for constructing the second well network mentioned above includes:

[0065] The above chemical flooding oil production rate function is constructed based on the second water-drive oil production rate and the chemical flooding enhancement rate in the second well network.

[0066] For example, the total recovery rate of the second and third oil production modes of the second well network is set to a certain value. The water-drive oil production rate of the second well network can be determined by the second water-drive oil production rate. When chemical flooding is used, the oil production rate will be increased by a certain amount based on the original water-drive oil production rate. That is, the chemical flooding oil production rate is determined by the sum of the water-drive oil production rate and the chemical flooding oil production rate increase rate. The chemical flooding oil production rate V zi It can be determined by equation (3):

[0067] V zi =V x(m+n) +V si (3)

[0068] In the formula, V x(m+n) V represents the oil recovery rate of waterflooding oil production during the m+n year data collection phase of the second well network. si To improve the oil recovery rate compared to waterflooding in chemical flooding.

[0069] In some examples, the above method also includes:

[0070] The rate of improvement of the chemical flooding was determined by numerical simulation, wherein the numerical simulation method includes Eclipse simulation or Cmg simulation.

[0071] For example, Eclipse and Cmg are two commonly used reservoir development simulation software programs. By setting reasonable boundary conditions and dividing appropriate grids, numerical simulation methods can be used to determine the rate of improvement of the second well network after adopting chemical flooding compared to water flooding.

[0072] In some examples, the above-mentioned economic benefit evaluation of the target oilfield using the presence-or-absence comparison method based on the first waterflooding oil recovery rate function, the second waterflooding oil recovery rate function, and the above-mentioned chemical flooding oil recovery rate function includes:

[0073] Based on the first water-drive oil production rate function, the second water-drive oil production rate function, and the chemical flooding oil production rate, the annual oil production rate of the target oilfield corresponding to different conversion schemes is determined. Among them, the water-drive oil production life m of the second well network corresponding to the different conversion schemes is different.

[0074] The economic benefits of different drive schemes are evaluated based on the annual oil production rate of the target oilfield.

[0075] For example, for the conversion scheme of the second well network to chemical flooding after water flooding for different years, the annual oil production rate of the target oil field under different conversion schemes is obtained, and the economic benefits of the target oil field are evaluated based on the annual oil production rate of the target oil field under different schemes, so as to determine the optimal timing for conversion.

[0076] In some examples, the above-mentioned economic benefit evaluation of different rotary displacement schemes based on the annual oil production rate of the target oilfield includes...

[0077] Calculate the annual sales revenue for each drive scheme based on the above annual oil production rate, geological reserves, and average annual oil price.

[0078] Calculate the total annual expenditure for each drive scheme based on the annual investment amount, annual working capital, and annual total cost.

[0079] Calculate the annual cash flow for each transformation scheme based on the above-mentioned annual sales revenue and total annual expenditure;

[0080] Based on the above cash flows, the internal rate of return under each transition scheme is determined using the IRR function;

[0081] The aforementioned internal rate of return is used in the aforementioned economic benefit evaluation;

[0082] The timing for converting the second well network from waterflooding to chemical flooding, determined based on the above economic benefit evaluation results, includes:

[0083] The conversion scheme corresponding to the maximum internal rate of return is determined as the timing for the conversion of the second well pattern from water flooding to chemical flooding.

[0084] For example, annual sales revenue can be determined by equation (4):

[0085] Annual sales revenue = Average annual oil price × N p ×V i (4)

[0086] In the formula, N p Geological reserves of the target oil field, V i Let be the annual oil production rate of the target oilfield. In the case that the second well network is in the second production mode, the annual oil production rate is the sum of the first water-drive oil production rate of the first well network and the second water-drive oil production rate of the second well network. If the second well network is in the third production mode, the annual oil production rate is the sum of the first water-drive oil production rate of the first well network and the chemical flooding oil production rate of the second well network.

[0087] Total annual expenditure can be determined by formula (5):

[0088] Total annual expenditure = Annual investment amount + Annual working capital + Annual total cost (5)

[0089] The annual cash flow can be determined by equation (6):

[0090] Annual cash flow = Annual sales revenue - Annual total expenditure (6)

[0091] Based on the annual cash flow of each conversion scheme, the internal rate of return (IRR) is determined using the IRR function. The conversion scheme with the highest IRR is selected as the timing for the second well network to switch from water drive to chemical drive.

[0092] In some examples, the above method also includes:

[0093] The total annual cost is calculated based on annual operating costs, annual chemical reagent costs, total period expenses, and annual taxes.

[0094] For example, the total annual cost can be determined by equation (7):

[0095] Total annual cost = Annual operating cost + Annual chemical reagent cost + Total period cost + Annual taxes (7)

[0096] Among them, annual operating cost refers to the cost of workers or machines working, annual chemical agent cost refers to the cost of chemical agents used when chemical flooding is adopted, total period cost refers to the cost of maintenance and repair of production equipment or other equipment during the production cycle, and annual taxes and fees refer to the taxes and fees payable each year.

[0097] In some examples, oil recovery rate curves can be plotted based on the first waterflooding oil recovery rate function, the second waterflooding oil recovery rate function, and the chemical flooding oil recovery rate function (e.g., Figure 2 As shown), and based on the oil production rate curve, the internal rate of return curves under different drive schemes can be constructed using the above method (e.g., Figure 3 As shown in the figure, consider different oil prices and repeat the above calculation steps to find the highest point of the curve, which is the best time to switch to the drive.

[0098] Please see Figure 4 One embodiment of the drive timing determination device in the two-three combined development mode of this application may include:

[0099] The first construction unit 41 is used to construct the first water-drive oil production rate function of the first well network and the second water-drive oil production rate function of the second well network, wherein the first well network is a well network drilled under the first development mode and the second well network is a well network drilled under the combined two and three development modes.

[0100] The second building unit 42 is used to build the chemical flooding oil recovery rate function of the second well network, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years that the second well network has adopted water flooding oil recovery.

[0101] Evaluation unit 43 is used to evaluate the economic benefits of the target oilfield by using a comparison method based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function and the chemical flooding oil recovery rate function.

[0102] Unit 44 is used to determine the timing of the conversion of the second well network from water drive to chemical drive based on the results of the above economic benefit evaluation.

[0103] like Figure 5 As shown, this application embodiment also provides an electronic device 300, including a memory 310, a processor 320, and a computer program 511 stored in the memory 310 and executable on the processor. When the processor 320 executes the computer program 311, it implements the steps of any of the methods for determining the drive timing in the above-mentioned two-three combined development mode.

[0104] Since the electronic device described in this embodiment is the device used to implement the drive timing determination device in a two-three combined development mode of this application embodiment, those skilled in the art can understand the specific implementation method and its various variations of the electronic device in this embodiment based on the method described in this application embodiment. Therefore, how the electronic device implements the method in this application embodiment will not be described in detail here. As long as those skilled in the art implement the method in this application embodiment, the device used is within the scope of protection of this application.

[0105] In practical implementation, when the computer program 311 is executed by the processor, it can achieve the following: Figure 1 Any of the corresponding implementation methods in the embodiments.

[0106] It should be noted that the descriptions of each embodiment in the above embodiments have different focuses. For parts that are not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0107] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0108] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded computer, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create a machine for implementing the flowchart illustrations. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0109] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0110] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0111] This application also provides a computer program product, which includes computer software instructions that, when executed on a processing device, cause the processing device to perform actions such as... Figure 1 The flowchart of the method for determining the timing of the transition drive under the two-three combined development mode in the corresponding embodiment.

[0112] A computer program product includes one or more computer instructions. When the computer program instructions are loaded and executed on a computer, all or part of the flow or function according to the embodiments of this application is generated. The computer may be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. The computer instructions may be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, computer instructions may be transmitted from one website, computer, server, or data center to another website, computer, server, or data center via wired (e.g., coaxial cable, fiber optic, digital subscriber line (DSL)) or wireless (e.g., infrared, wireless, microwave, etc.) means. The computer-readable storage medium may be any available medium that a computer can store or a data storage device such as a server or data center that integrates one or more available media. The available medium may be a magnetic medium (e.g., floppy disk, hard disk, magnetic tape), an optical medium (e.g., DVD), or a semiconductor medium (e.g., solid-state disk (SSD)).

[0113] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0114] In the several embodiments provided in this application, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, or indirect coupling or communication connection between apparatuses or units, and may be electrical, mechanical, or other forms.

[0115] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0116] Furthermore, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0117] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0118] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application.

Claims

1. A method for determining the timing of a transition drive in a two- or three-way combined development model, characterized in that, include: The first water drive oil production rate function of the first well network and the second water drive oil production rate function of the second well network are constructed respectively. The first well network is the well network drilled under the first development mode, and the second well network is the well network drilled under the combined two and three development modes. Construct the chemical flooding oil recovery rate function of the second well network, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years the second well network has used water flooding oil recovery. The economic benefits of the target oilfield are evaluated using a comparison method based on the presence or absence of the first water-drive oil recovery rate function, the second water-drive oil recovery rate function, and the chemical flooding oil recovery rate function. This evaluation includes: determining the annual oil recovery rate of the target oilfield corresponding to different conversion schemes based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function, and the chemical flooding oil recovery rate, wherein the water-drive oil recovery lifespan (m) of the second well network corresponding to the different conversion schemes is different; and evaluating the economic benefits under different conversion schemes based on the annual oil recovery rate of the target oilfield. The economic benefit evaluation of different conversion schemes based on the annual oil production rate of the target oilfield includes: calculating the annual sales revenue of each conversion scheme based on the annual oil production rate, geological reserves, and average annual oil price; calculating the annual total expenditure of each conversion scheme based on the annual investment amount, annual working capital, and annual total cost; obtaining the annual cash flow of each conversion scheme based on the annual sales revenue and the annual total expenditure; determining the internal rate of return (IRR) of each conversion scheme based on the cash flow using the IRR function; and using the IRR for the economic benefit evaluation. The determination of the conversion timing for the second well network from water drive to chemical drive based on the results of the economic benefit evaluation includes: identifying the conversion scheme corresponding to the highest IRR as the conversion timing for the second well network from water drive to chemical drive. The timing for converting the second well network from water-drive to chemical-drive will be determined based on the results of the economic benefit evaluation.

2. The method as described in claim 1, characterized in that, The construction of the first waterdrive oil production rate function for the first well pattern and the second waterdrive oil production rate function for the second well pattern includes: By combining historical production data, a first water-drive oil production rate function for the first well network and a second water-drive oil production rate function for the second well network are constructed, wherein the first water-drive oil production rate function and the second water-drive oil production rate function are in exponential form.

3. The method as described in claim 1, characterized in that, The chemical flooding production rate function for constructing the second well pattern includes: The chemical flooding production rate function is constructed based on the second water-drive production rate and the chemical flooding enhancement rate in the second well network.

4. The method as described in claim 3, characterized in that, Also includes: The chemical flooding enhancement rate is determined using numerical simulation, wherein the numerical simulation includes Eclipse simulation or Cmg simulation.

5. The method as described in claim 1, characterized in that, Also includes: The total annual cost is calculated based on annual operating costs, annual chemical reagent costs, total period expenses, and annual taxes.

6. A device for determining the timing of a drive in a two- or three-way combined development model, characterized in that, include: The first construction unit is used to construct the first water-drive oil production rate function of the first well network and the second water-drive oil production rate function of the second well network, wherein the first well network is a well network drilled under the first development mode and the second well network is a well network drilled under the combined two-three development mode. The second construction unit is used to construct the chemical flooding oil recovery rate function of the second well network, wherein the chemical flooding oil recovery rate function is the chemical flooding oil recovery rate function of the second well network after m years of water flooding oil recovery, where m is the number of years that the second well network has used water flooding oil recovery. The evaluation unit is used to evaluate the economic benefits of a target oilfield using a comparison method based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function, and the chemical flooding oil recovery rate function. The evaluation of the economic benefits of the target oilfield using a comparison method based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function, and the chemical flooding oil recovery rate function includes: determining the annual oil recovery rate of the target oilfield corresponding to different conversion schemes based on the first water-drive oil recovery rate function, the second water-drive oil recovery rate function, and the chemical flooding oil recovery rate, wherein the water-drive oil recovery lifespan m of the second well network corresponding to the different conversion schemes is different; evaluating the economic benefits under different conversion schemes based on the annual oil recovery rate of the target oilfield; and further evaluating the economic benefits based on the target oilfield's annual oil recovery rate. The economic benefit evaluation of the field's annual oil production rate under different conversion schemes includes: calculating the annual sales revenue under each conversion scheme based on the annual oil production rate, geological reserves, and average annual oil price; calculating the annual total expenditure under each conversion scheme based on the annual investment amount, annual working capital, and annual total cost; obtaining the annual cash flow under each conversion scheme based on the annual sales revenue and annual total expenditure; determining the internal rate of return (IRR) under each conversion scheme based on the cash flow; using the IRR function for the economic benefit evaluation; and determining the conversion timing of the second well network from water drive to chemical drive based on the results of the economic benefit evaluation, including: determining the conversion scheme corresponding to the highest IRR as the conversion timing of the second well network from water drive to chemical drive. The determining unit is used to determine the timing of the conversion of the second well network from water drive to chemical drive based on the results of the economic benefit evaluation.

7. An electronic device, comprising: A memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that the processor, when executing the computer program stored in the memory, implements the steps of the method for determining the timing of a transition drive under a two- or three-way combined development mode as described in any one of claims 1-5.

8. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by the processor, it implements the method for determining the timing of the transition drive under the two-three combined development mode as described in any one of claims 1-5.

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