A method and device for calculating the production profile of a horizontal well based on multi-pass combination

Abstract

The application discloses a kind of based on horizontal well production profile flow calculation method and device of multiple joint, through multiple probe array detection instrument in the same depth range of wellbore multiple times of measurement are carried out, the measurement data of multiple probes corresponding to each time are obtained;For each depth point in depth range, the measurement position of multiple probes corresponding to multiple times is jointly superimposed, and the projection position of each probe in the radial direction of wellbore after joint is determined;According to the projection position of each probe, the radial projection area of each probe is obtained;According to the measurement data of each probe, the radial projection area of each probe and the radial area of wellbore, the total flow of wellbore fluid is calculated.The method of the application can obtain more accurate horizontal well production profile, and can improve interpretation accuracy in the case where some probes fail.

Description

Technical Field

[0001] This invention relates to the field of production profile flow rate technology, and specifically to a method and apparatus for calculating production profile flow rate of horizontal wells based on multiple combined runs. Background Technology

[0002] Multi-probe logging instruments designed for production logging in horizontal wells are widely used in both onshore and offshore oilfields, demonstrating excellent performance in water detection within oil wells. Production profile logging refers to a logging method used in oil and gas production wells to determine the quantity of oil, gas, and water produced in each layer. To obtain a fluid flow profile and ensure the accuracy and validity of the data, production profile logging measurements require multiple runs at different measurement rates. Current technologies for horizontal well production profile logging often employ array instrument calculation methods. This method typically calculates the array probe data for each run individually and then performs an arithmetic average to obtain the flow rate within the wellbore.

[0003] However, in actual horizontal well production profile logging operations, due to complex downhole conditions, one or more turbines in the array probe may fail in one measurement run but be effective in another. Existing calculation methods require discarding data from that particular run, resulting in data waste. Therefore, to improve interpretation accuracy and enhance the comprehensive utilization of logging data, a new method for calculating horizontal well production profile logging flow rate is needed. Summary of the Invention

[0004] In view of the above problems, the present invention is proposed to provide a method and apparatus for calculating the production profile flow rate of a multi-pass horizontal well in order to overcome or at least partially solve the above problems.

[0005] According to one aspect of the present invention, a method for calculating the production profile flow rate based on multiple combined horizontal well runs is provided, comprising:

[0006] By using an array of probes to measure the same depth range in the wellbore multiple times, measurement data from multiple probes are obtained for each time.

[0007] For each depth point within the specified depth range, the measurement positions of multiple probes corresponding to multiple passes are combined and superimposed, and the combined projection position of each probe on the radial direction of the wellbore is determined.

[0008] Based on the projection position of each probe, the radial projection area of ​​each probe is obtained;

[0009] The total flow rate of the fluid in the wellbore is calculated based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore.

[0010] According to another aspect of the present invention, a device for calculating the production profile flow rate of multiple horizontal wells in combination is provided, comprising:

[0011] The data acquisition module is used to perform multiple measurements in the same depth range of the wellbore using an array of detection instruments with multiple probes, and to obtain the measurement data of multiple probes corresponding to each trip;

[0012] The multi-pass combined module is used to combine and superimpose the measurement positions of multiple probes corresponding to multiple passes for each depth point within the depth range;

[0013] The projection module is used to determine the radial projection position of each probe after assembly in the wellbore; based on the projection position of each probe, the radial projection area of ​​each probe is obtained;

[0014] The calculation module is used to calculate the total flow rate of the fluid in the wellbore based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore.

[0015] According to another aspect of the present invention, a computing device is provided, comprising: a processor, a memory, a communication interface, and a communication bus, wherein the processor, the memory, and the communication interface communicate with each other via the communication bus;

[0016] The memory is used to store at least one executable instruction, which causes the processor to perform the operation corresponding to the above-described method for calculating the production profile flow rate of a horizontal well based on multiple combined runs.

[0017] According to another aspect of the present invention, a computer storage medium is provided, the storage medium storing at least one executable instruction, the executable instruction causing a processor to perform an operation corresponding to the above-described method for calculating the production profile flow rate of a multi-pass combined horizontal well.

[0018] According to the present invention, a method and apparatus for calculating the production profile flow rate of a horizontal well based on multiple passes is used. An array of probes is used to perform multiple measurements within the same depth range of the wellbore, obtaining measurement data from multiple probes for each pass. For each depth point within the depth range, the measurement positions of the multiple probes from multiple passes are jointly superimposed, and the radial projection position of each probe in the wellbore is determined. Based on the projection position of each probe, the radial projection area of ​​each probe is obtained. Based on the measurement data of each probe, the radial projection area of ​​each probe, and the radial area of ​​the wellbore, the total flow rate of the wellbore fluid is calculated. This invention utilizes an array of probes to acquire measurement data from multiple passes, and then superimposes the measurement data. Based on the consistency of the axial fluid properties of the stratified flow in horizontal wells, the measurement positions of the superimposed probes are projected onto the diameter direction of the wellbore. An area-weighted average method is used to obtain the flow rate of the entire wellbore. Compared with the existing method of calculating separately for each pass, the method of this invention can obtain a more accurate horizontal well production profile, especially improving interpretation accuracy in the case of probe failure.

[0019] The above description is merely an overview of the technical solution of the present invention. In order to better understand the technical means of the present invention and to implement it in accordance with the contents of the specification, and in order to make the above and other objects, features and advantages of the present invention more apparent and understandable, specific embodiments of the present invention are described below. Attached Figure Description

[0020] 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 the invention. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0021] Figure 1 The flowchart of a method for calculating the production profile flow rate of a horizontal well based on multiple combined runs, provided by an embodiment of the present invention, is shown.

[0022] Figure 2a This diagram illustrates the process of jointly superimposing measurement data in an embodiment of the present invention.

[0023] Figure 2b A schematic diagram of the radial projection process in an embodiment of the present invention is shown;

[0024] Figure 3 This diagram illustrates the structure of a multi-pass combined horizontal well production profile flow calculation device provided by an embodiment of the present invention.

[0025] Figure 4A schematic diagram of the structure of a computing device provided in an embodiment of the present invention is shown. Detailed Implementation

[0026] Exemplary embodiments of the invention will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the invention are shown in the drawings, it should be understood that the invention may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this invention will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.

[0027] Figure 1 A flowchart illustrating an embodiment of the present invention, namely a method for calculating the production profile flow rate of a horizontal well based on multiple combined runs, is shown. Figure 1 As shown, the method includes the following steps:

[0028] Step S110: Perform multiple measurements in the same depth range of the wellbore using an array detection instrument with multiple probes to obtain measurement data from multiple probes for each measurement.

[0029] In this step, an array detection instrument with multiple probes performs multiple measurements within the same depth range of the wellbore to obtain measurement data from multiple probes for each measurement. For example, an array detection instrument with m probes performs n measurements within the same depth range of the wellbore to obtain measurement data from m probes for n measurements.

[0030] In an alternative approach, step S110 further includes: performing multiple measurements in the same depth range of the wellbore using an array of probes to obtain measurement data from the multiple probes corresponding to each measurement.

[0031] Specifically, array detection instruments may include: array turbine flow meters (SAT), etc. Figure 2a This is a schematic diagram illustrating the process of jointly superimposing measurement data in this embodiment, as shown below. Figure 2a As shown, taking an array turbine flow meter with 6 probes as an example, the 6 probes can be evenly distributed around the wellbore during measurement. By using the array turbine flow meter with 6 probes to perform multiple measurements in a certain depth range (such as 1000-1500 meters) in the wellbore, the measurement data of the 6 probes corresponding to each measurement can be obtained.

[0032] Step S120: For each depth point within the depth range, the measurement positions of multiple probes corresponding to multiple passes are combined and superimposed, and the projection position of each probe in the radial direction of the wellbore is determined.

[0033] In this step, for each depth point within the depth range, the measurement positions of multiple probes corresponding to multiple passes are jointly superimposed. Since the array probe rotates during measurement, the measurement positions of the multiple probes differ for each pass. Therefore, for each depth point, based on the rotation angle of the array probe, the measurement positions of the multiple probes corresponding to multiple passes can be jointly superimposed. For example... Figure 2a As shown, by jointly superimposing the measurement positions of the six probes corresponding to two passes at each depth point, the result can be obtained. Figure 2a The measurement data from the 12 probes shown on the far right.

[0034] In an alternative approach, step S120 further includes: projecting each probe after being joined along the diameter direction of the wellbore to obtain the projected position of each probe.

[0035] Specifically, since the axial fluid properties of the layered flow in a horizontal well are consistent and differ only in the radial direction, the radial information can represent all the axial information at that location. In this step, each probe after being combined can be projected along the diameter of the wellbore to obtain the projected position of each probe. Figure 2b This is a schematic diagram of the radial projection process in this embodiment, as shown below. Figure 2b As shown, the measurement positions of the six probes corresponding to two passes at each depth point are combined and superimposed. The combined 12 probes are then projected along the diameter of the wellbore to obtain the projected position of each probe.

[0036] Step S130: Based on the projection position of each probe, obtain the radial projection area of ​​each probe.

[0037] In an optional manner, step S130 further includes: calculating the distance of each probe from a specified side of the wellbore based on the projection position of each probe; dividing the radial area of ​​the wellbore according to the distance of each probe from the specified side of the wellbore and the diameter of the wellbore to obtain the radial projected area of ​​each probe.

[0038] Specifically, the designated side of a horizontal wellbore can be either the high side (upper side) or the low side (lower side). Taking the high side as an example, for instance... Figure 2b As shown, based on the projection position of each probe, the distances of the 12 SAT probes from the high side of the wellbore are obtained. According to the distance of each probe from the specified side of the wellbore and the diameter of the wellbore, the radial area of ​​the wellbore is divided to obtain the radial projected area of ​​each probe. Since the number of probes after joint superposition is more than the number of probes in a single pass, the division of the radial distance of the entire wellbore is also more refined. The measurement data of the 6 probes in 2 passes can be divided into 12 tiny areas.

[0039] Step S140: Calculate the total flow rate of the fluid in the wellbore based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore.

[0040] In an optional manner, step S140 further includes: calculating the area ratio of each probe as the weight of each probe based on the radial projected area of ​​each probe and the radial area of ​​the wellbore; and performing a weighted calculation on the measurement data of each probe according to the weight of each probe to obtain the total flow rate of the wellbore fluid.

[0041] Specifically, the weight of each probe is determined by the ratio of its radial projected area to the radial area of ​​the wellbore. The measurement data from each probe are then weighted according to this weight to obtain the total flow rate of the fluid in the wellbore. It should be noted that, since the example SAT instrument provided in this embodiment has an internal cylinder, for accuracy, the radial area of ​​the wellbore in the following calculations is the actual radial area of ​​the wellbore minus the cross-sectional area of ​​the cylinder inside the SAT instrument.

[0042] In one alternative approach, the measurement data includes at least: turbine measurements for each probe, turbine start-up speed for each probe, intersection slope for each probe, and cable speed.

[0043] In an alternative embodiment, step S140 further includes: calculating the apparent fluid velocity value of each probe based on the turbine measurement value of each probe, the turbine start-up speed of each probe, the intersection slope of each probe, and the cable speed; and performing a weighted calculation on the apparent fluid velocity value of each probe according to the pipe constant and the weight of each probe to obtain the total flow rate of the well fluid.

[0044] Specifically, the apparent fluid velocity value V for each probe i It can be calculated using the following formula (1):

[0045]

[0046] Among them, V i The apparent fluid velocity value of the i-th probe (taking 12 probes as an example, i = 1, 2, ..., 12); RPS i K represents the turbine measurement value of the i-th probe; i Let V be the intersection slope of the i-th probe. ti V represents the turbine start-up speed of the i-th probe. l This refers to the cable speed.

[0047] The apparent fluid velocity value V of each probe is assigned according to its weight. i A weighted average is performed to obtain the average velocity V of the fluid inside the wellbore. mThe calculation formula is as follows (2):

[0048]

[0049] Among them, S i V is the radial projected area of ​​the i-th probe; S is the radial area of ​​the wellbore (the area occupied by the internal cylindrical cross-section of the array detection instrument needs to be removed); V i The apparent fluid velocity value for each probe; V m denoted as , where is the average velocity of the fluid inside the wellbore; and 'n' is the total number of probes.

[0050] The total flow rate Q of the wellbore fluid is calculated based on the pipe constant and the average velocity of the fluid inside the wellbore. t As shown in equation (3):

[0051] Q t =V m ×P c (3)

[0052] Among them, P c This is the tube constant, with units of (m). 3 / d) / (m / min); V m The average velocity of the fluid inside the wellbore obtained by equation (2); Q t This represents the total flow rate of the fluid in the wellbore.

[0053] Using the method of this embodiment, the total flow rate of the wellbore fluid was calculated in a basically consistent manner with the existing well logging interpretation software Emeraude. Table 1 shows the data comparison between this embodiment and Emeraude software. As shown in Table 1, the total flow rate Q of the wellbore fluid in the same section is... t and the average velocity V of the fluid inside the wellbore m This embodiment differs little from the Emeraude software. The absolute error calculation formula is as follows (4):

[0054] Absolute error = Value calculated in this embodiment - Emeraude software value; (4)

[0055] The formula for calculating the relative error is as follows (5):

[0056]

[0057] As can be seen from Table 1, the calculation results of absolute error and relative error are also small. Therefore, the method in this embodiment has high calculation accuracy and precision.

[0058]

[0059] Table 1 Comparison of data between this embodiment and Emeraude software.

[0060] The method described in this embodiment utilizes an array of probes to acquire measurement data from multiple runs. This data is then combined and superimposed. Based on the consistency of axial fluid properties in the stratified flow of horizontal wells, the measurement positions of the combined probes are projected onto the wellbore diameter direction. An area-weighted average method is then used to obtain the flow rate of the entire wellbore. Compared to existing methods that calculate data separately for each run, this method, due to the increased number of probes, provides a more accurate horizontal well production profile. It is particularly effective in improving interpretation accuracy when some probes fail, effectively solving the problem of data unusable when some probes fail during multiple wellbore measurements. This provides a valid basis for water exploration and improved oil and gas recovery in offshore oilfield gas production wells.

[0061] Figure 3 A schematic diagram of an embodiment of the present invention, a horizontal well production profile flow rate calculation device based on multiple combined runs, is shown. Figure 3 As shown, the device includes: a data acquisition module 310, a multi-pass joint module 320, a projection module 330, and a calculation module 340.

[0062] The data acquisition module 310 is used to perform multiple measurements in the same depth range of the wellbore using an array detection instrument with multiple probes, and to obtain the measurement data of multiple probes corresponding to each trip.

[0063] The multi-pass combined module 320 is used to combine and superimpose the measurement positions of multiple probes corresponding to multiple passes for each depth point within the depth range.

[0064] The projection module 330 is used to determine the radial projection position of each probe after assembly in the wellbore; based on the projection position of each probe, the radial projection area of ​​each probe is obtained.

[0065] In an alternative embodiment, the projection module 330 is further configured to: project each of the combined probes along the diameter of the wellbore to obtain the projected position of each probe.

[0066] In an alternative embodiment, the projection module 330 is further configured to: calculate the distance of each probe from a specified side of the wellbore based on the projection position of each probe; and divide the radial area of ​​the wellbore according to the distance of each probe from the specified side of the wellbore and the diameter of the wellbore to obtain the radial projected area of ​​each probe.

[0067] The calculation module 340 is used to calculate the total flow rate of the well fluid based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the well.

[0068] In an alternative embodiment, the calculation module 340 is further configured to: calculate the area ratio of each probe as the weight of each probe based on the radial projected area of ​​each probe and the radial area of ​​the wellbore; and perform a weighted calculation on the measurement data of each probe according to the weight of each probe to obtain the total flow rate of the wellbore fluid.

[0069] In one alternative approach, the measurement data includes at least: turbine measurements for each probe, turbine start-up speed for each probe, intersection slope for each probe, and cable speed.

[0070] In an alternative embodiment, the calculation module 340 is further configured to: calculate the apparent fluid velocity value of each probe based on the turbine measurement value of each probe, the turbine start-up speed of each probe, the intersection slope of each probe, and the cable speed; and perform a weighted calculation on the apparent fluid velocity value of each probe according to the pipe constant and the weight of each probe to obtain the total flow rate of the well fluid.

[0071] The apparatus of this embodiment utilizes an array of probes to acquire measurement data from multiple runs. The measurement data is then combined and superimposed. Based on the consistency of the axial fluid properties of the stratified flow in horizontal wells, the measurement positions of the combined and superimposed probes are projected onto the wellbore diameter direction. An area-weighted average method is used to obtain the flow rate of the entire wellbore. Compared with the prior art, due to the increased number of probes, a more accurate horizontal well production profile can be obtained than the existing method of calculating separately for each run. In particular, it can improve the interpretation accuracy when some probes fail, and can effectively solve the problem that data cannot be used when some probes fail during multiple wellbore measurements.

[0072] This invention provides a non-volatile computer storage medium storing at least one executable instruction that can execute a method for calculating the production profile flow rate of a horizontal well based on multiple combined runs, as described in any of the above method embodiments.

[0073] Executable instructions can specifically be used to cause the processor to perform the following operations:

[0074] By using an array of probes to measure the same depth range in the wellbore multiple times, measurement data from multiple probes are obtained for each time.

[0075] For each depth point within the specified depth range, the measurement positions of multiple probes corresponding to multiple passes are combined and superimposed, and the combined projection position of each probe on the radial direction of the wellbore is determined.

[0076] Based on the projection position of each probe, the radial projection area of ​​each probe is obtained;

[0077] The total flow rate of the fluid in the wellbore is calculated based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore.

[0078] Figure 4 The diagram shows a structural schematic of an embodiment of the computing device of the present invention. The specific embodiments of the present invention do not limit the specific implementation of the computing device.

[0079] like Figure 4 As shown, the computing device may include:

[0080] Processor, Communications Interface, Memory, and Communications Bus.

[0081] The processor, communication interface, and memory communicate with each other via a communication bus. The communication interface is used to communicate with other network elements, such as clients or other servers. The processor executes programs, specifically the relevant steps in the embodiment of the method for calculating the production profile flow rate of a multi-pass horizontal well.

[0082] Specifically, the program may include program code, which includes computer operation instructions.

[0083] The processor may be a central processing unit (CPU), an application-specific integrated circuit (ASIC), or one or more integrated circuits configured to implement embodiments of the present invention. The server may include one or more processors of the same type, such as one or more CPUs; or it may include processors of different types, such as one or more CPUs and one or more ASICs.

[0084] Memory is used to store programs. Memory may include high-speed RAM, and may also include non-volatile memory, such as at least one disk drive.

[0085] Specifically, the program can be used to cause the processor to perform the following operations:

[0086] By using an array of probes to measure the same depth range in the wellbore multiple times, measurement data from multiple probes are obtained for each time.

[0087] For each depth point within the specified depth range, the measurement positions of multiple probes corresponding to multiple passes are combined and superimposed, and the combined projection position of each probe on the radial direction of the wellbore is determined.

[0088] Based on the projection position of each probe, the radial projection area of ​​each probe is obtained;

[0089] The total flow rate of the fluid in the wellbore is calculated based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore.

[0090] The algorithms or displays provided herein are not inherently related to any particular computer, virtual system, or other device. Various general-purpose systems can also be used in conjunction with the teachings herein. The required structure for constructing such systems is apparent from the above description. Furthermore, the embodiments of the present invention are not directed to any particular programming language. It should be understood that the content of the invention described herein can be implemented using various programming languages, and the above description of specific languages ​​is for the purpose of disclosing the best mode of implementation of the invention.

[0091] Numerous specific details are set forth in the specification provided herein. However, it will be understood that embodiments of the invention may be practiced without these specific details. In some instances, well-known methods, structures, and techniques have not been shown in detail so as not to obscure the understanding of this specification.

[0092] Similarly, it should be understood that, in order to simplify the invention and aid in understanding one or more of the various inventive aspects, features of the embodiments of the invention are sometimes grouped together in a single embodiment, figure, or description thereof in the above description of exemplary embodiments of the invention. However, this disclosure should not be construed as reflecting an intention that the claimed invention requires more features than are expressly recited in each claim. Rather, as reflected in the following claims, inventive aspects lie in fewer than all features of a single foregoing disclosed embodiment. Therefore, the claims following the detailed description are hereby expressly incorporated into this detailed description, wherein each claim itself is a separate embodiment of the invention.

[0093] Those skilled in the art will understand that modules in the device of the embodiments can be adaptively changed and placed in one or more devices different from that embodiment. Modules, units, or components in the embodiments can be combined into a single module, unit, or component, and further, they can be divided into multiple sub-modules, sub-units, or sub-components. Except where at least some of such features and / or processes or units are mutually exclusive, any combination can be used to combine all features disclosed in this specification (including the accompanying claims, abstract, and drawings) and all processes or units of any method or device so disclosed. Unless expressly stated otherwise, each feature disclosed in this specification (including the accompanying claims, abstract, and drawings) may be replaced by an alternative feature that serves the same, equivalent, or similar purpose.

[0094] Furthermore, those skilled in the art will understand that although some embodiments herein include certain features included in other embodiments but not others, combinations of features from different embodiments are intended to be within the scope of the invention and form different embodiments. For example, in the following claims, any of the claimed embodiments can be used in any combination.

[0095] The various component embodiments of the present invention can be implemented in hardware, or as software modules running on one or more processors, or a combination thereof. Those skilled in the art will understand that microprocessors or digital signal processors (DSPs) can be used in practice to implement some or all of the functions of some or all of the components according to the embodiments of the present invention. The present invention can also be implemented as a device or apparatus program (e.g., a computer program and computer program product) for performing part or all of the methods described herein. Such programs implementing the present invention can be stored on a computer-readable medium, or can be in the form of one or more signals. Such signals can be downloaded from an Internet website, provided on a carrier signal, or provided in any other form.

[0096] It should be noted that the above embodiments are illustrative of the invention and not restrictive, and that those skilled in the art can devise alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses should not be construed as limiting the claims. The word "comprising" does not exclude the presence of elements or steps not listed in the claims. The word "a" or "an" preceding an element does not exclude the presence of a plurality of such elements. The invention can be implemented by means of hardware comprising several different elements and by means of a suitably programmed computer. In the unit claims enumerating several means, several of these means may be embodied by the same item of hardware. The use of the words first, second, and third, etc., does not indicate any order. These words can be interpreted as names. The steps in the above embodiments, unless otherwise specified, should not be construed as limiting the order of execution.

Claims

1. A method for calculating the production profile flow rate of a horizontal well based on multiple combined runs, characterized in that, include: By using an array of probes to measure the same depth range in the wellbore multiple times, measurement data from multiple probes are obtained for each time. For each depth point within the aforementioned depth range, based on the rotation angle of the array detection instrument, the measurement positions of multiple probes corresponding to multiple passes are combined and superimposed, and the combined projection position of each probe on the radial side of the wellbore is determined. Based on the projection position of each probe, the radial projection area of ​​each probe is obtained; Based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore, the total flow rate of the fluid in the wellbore is calculated; The step of calculating the total flow rate of the wellbore fluid based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore further includes: Based on the radial projected area of ​​each probe and the radial area of ​​the wellbore, the area ratio of each probe is calculated as the weight of each probe; The apparent fluid velocity values ​​of each probe are weighted and averaged according to their respective weights to obtain the average velocity of the fluid inside the wellbore; wherein, the apparent fluid velocity value of each probe is calculated based on the measurement data of each probe. The total flow rate of the well fluid is calculated based on the pipe constant and the average velocity of the fluid inside the well. The formula for calculating the average velocity of the fluid inside the wellbore is as follows: Among them, S i V is the radial projected area of ​​the i-th probe; S is the radial area of ​​the wellbore; V i The apparent fluid velocity value for each probe; V m is the average velocity of the fluid inside the wellbore; n is the total number of probes; The formula for calculating the total flow rate of the well fluid is: Q t =V m ×P c ; Among them, P c V is the tube constant; m Q represents the average velocity of the fluid inside the wellbore. t This represents the total flow rate of the fluid in the wellbore.

2. The method according to claim 1, characterized in that, Determining the radial projection position of each probe after combination in the wellbore further includes: Each probe, after being combined, is projected along the diameter of the wellbore to obtain the projected position of each probe.

3. The method according to claim 1, characterized in that, The step of obtaining the radial projected area of ​​each probe based on its projected position further includes: Based on the projected position of each probe, calculate the distance of each probe from a specified side of the wellbore; Based on the distance of each probe from a specified side of the well shaft and the diameter of the well shaft, the radial area of ​​the well shaft is divided to obtain the radial projected area of ​​each probe.

4. The method according to claim 1, characterized in that, The measurement data includes at least: turbine measurements for each probe, turbine start-up speed for each probe, intersection slope for each probe, and cable speed.

5. The method according to claim 4, characterized in that, The method further includes: The apparent fluid velocity value for each probe is calculated based on the turbine measurement value, turbine start-up speed, intersection slope, and cable speed of each probe.

6. A device for calculating the production profile flow rate of a horizontal well based on multiple combined runs, characterized in that, include: The data acquisition module is used to perform multiple measurements in the same depth range of the wellbore using an array of detection instruments with multiple probes, and to obtain the measurement data of multiple probes corresponding to each trip; The multi-pass combined module is used to combine and superimpose the measurement positions of multiple probes corresponding to multiple passes for each depth point within the depth range, based on the rotation angle of the array detection instrument. The projection module is used to determine the radial projection position of each probe after assembly in the wellbore; based on the projection position of each probe, the radial projection area of ​​each probe is obtained; The calculation module is used to calculate the total flow rate of the fluid in the wellbore based on the measurement data of each probe, the radial projected area of ​​each probe, and the radial area of ​​the wellbore. The calculation module is further used for: Based on the radial projected area of ​​each probe and the radial area of ​​the wellbore, the area ratio of each probe is calculated as the weight of each probe; The apparent fluid velocity values ​​of each probe are weighted and averaged according to their respective weights to obtain the average velocity of the fluid inside the wellbore; wherein, the apparent fluid velocity value of each probe is calculated based on the measurement data of each probe. The total flow rate of the well fluid is calculated based on the pipe constant and the average velocity of the fluid inside the well. The formula for calculating the average velocity of the fluid inside the wellbore is as follows: Among them, S i V is the radial projected area of ​​the i-th probe; S is the radial area of ​​the wellbore; V i The apparent fluid velocity value for each probe; V m is the average velocity of the fluid inside the wellbore; n is the total number of probes; The formula for calculating the total flow rate of the well fluid is: Q t =V m ×P c ; Among them, P c V is the tube constant; m Q represents the average velocity of the fluid inside the wellbore. t This represents the total flow rate of the fluid in the wellbore.

7. A computing device, characterized in that, include: The processor, memory, communication interface, and communication bus are provided, wherein the processor, memory, and communication interface communicate with each other via the communication bus. The memory is used to store at least one executable instruction that causes the processor to perform an operation corresponding to the method for calculating the production profile flow rate of a multi-pass joint horizontal well as described in any one of claims 1-5.

8. A computer storage medium, characterized in that, The storage medium stores at least one executable instruction that causes the processor to perform the operation corresponding to the method for calculating the production profile flow rate of a multi-pass horizontal well as described in any one of claims 1-5.

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