Horizontal well liquid production profile detection method based on magnetic resonance multiphase flowmeter

Abstract

The invention relates to the technical field of oilfield development, in particular to a horizontal well liquid production profile detection method based on a magnetic resonance multiphase flowmeter, the inlet end of the magnetic resonance multiphase flowmeter is connected with the oil outlet end of a coiled tubing through a well control device of a well mouth, and the outlet end of the magnetic resonance multiphase flowmeter is connected with an output pipeline. The oil inlet end of the coiled tubing is arranged at a target layer section of the horizontal well; the method comprises the steps that the flow velocity of produced liquid of a target layer section is obtained through a magnetic resonance multiphase flowmeter; a magnetic resonance multiphase flowmeter is used for obtaining the phase volume fraction of produced liquid of the target layer section; calculating the fluid yield of the target layer section based on the flow velocity and the phase volume fraction of the produced liquid and the pipe diameter of the coiled tubing; repeating the above steps until the measurement of the fluid yields of all layer sections of the horizontal well is completed; the fluid yield of each layer section of the horizontal well is matched with the measurement depth, and a horizontal well fluid production profile is drawn. By adopting the method, the problems of high cost, unstable precision, influence on production time efficiency and the like of the existing production logging technology can be solved.

Description

Technical Field

[0001] The present application relates to the technical field of oilfield development, and in particular to a method for detecting a production profile of a horizontal well based on a magnetic resonance multiphase flowmeter. Background Art

[0002] Horizontal wells can increase the production capacity of oil and gas wells and are suitable for the exploitation of low-permeability, low-pressure, heavy oil and other types of reservoirs. They can achieve high production in sparse wells. In recent years, the number of horizontal wells in newly drilled wells at home and abroad has increased year by year. The production dynamic evaluation of horizontal wells, especially the monitoring of the segmented output of each fracturing section of the horizontal well and the main production layer section, is becoming increasingly important for the design, transformation and production management of horizontal wells in the future. Although the existing production logging technology can basically meet the production needs for the production dynamic evaluation of vertical wells, these technologies cannot completely solve the problems that arise in horizontal wells when applied to horizontal wells. For example, in horizontal wells completed with slotted liner, bypass flow is prone to occur in the annular space between the slotted liner and the formation, causing the logging instrument to be unsuitable or even fail. In addition, due to the separation of oil, gas and water in the wellbore under the action of gravity, the flow pattern of the mixed fluid is complex and changeable. In addition, the long-distance undulation of the horizontal wellbore and other reasons make the horizontal flow production profile extremely complex. This brings great difficulties to the evaluation of the production dynamics of such oil and gas wells by production logging technology. It is difficult to solve a series of problems such as the flow distribution of the fluid in the entire horizontal well section, the inflow point of oil, gas and water, the well section of the production fluid, and the contribution rate of the horizontal section to the total flow.

[0003] In the field of petroleum industry, with the increasing depletion of conventional oil and gas resources and the deepening of unconventional oil and gas resource development, the underground fluids faced by the field of oil drilling and production engineering are mainly oil-water two-phase mixed fluids. Among them, shale oil and heavy oil, as important unconventional oil and gas resources, have very serious emulsification phenomenon. They are in the state of oil-in-water and water-in-oil in the pipeline for a long time. In addition, the problem of sand production in the well has brought great difficulties to the measurement and testing of oil and gas. Conventional production logging methods cannot effectively measure the three-phase production of oil, gas and water in each section of the horizontal well. Summary of the invention

[0004] The purpose of the embodiment of the present application is to provide a method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter.

[0005] In order to achieve the above-mentioned object, the present application provides a method for detecting a production profile of a horizontal well based on a magnetic resonance multiphase flowmeter, wherein the inlet end of the magnetic resonance multiphase flowmeter is connected to the oil outlet end of a coiled tubing through a well control device at a wellhead, the outlet end of the magnetic resonance multiphase flowmeter is connected to an external transmission pipeline, and the oil inlet end of the coiled tubing is arranged at a target layer section of the horizontal well; the method for detecting a production profile of a horizontal well comprises:

[0006] A1. Use a magnetic resonance multiphase flowmeter to obtain the flow rate of the produced fluid in the target layer;

[0007] A2. Use a magnetic resonance multiphase flowmeter to obtain the phase content of the produced fluid in the target layer;

[0008] A3. Calculate the fluid production of the target layer based on the flow rate, phase content and diameter of the coiled tubing of the produced fluid;

[0009] A4. Repeat steps A1 to A3 until the fluid production of all layers of the horizontal well is measured;

[0010] A5. Match the fluid production of each layer of the horizontal well with the measured depth and draw the horizontal well fluid production profile.

[0011] In some embodiments of the present application, the magnetic resonance multiphase flowmeter has two operating modes: a flow measurement mode and a static measurement mode; the magnetic resonance multiphase flowmeter operating in the flow measurement mode is used to measure the flow rate of the produced fluid, and the magnetic resonance multiphase flowmeter operating in the static measurement mode is used to measure the phase content of the produced fluid.

[0012] In some embodiments of the present application, the magnetic resonance multiphase flowmeter includes a main pipeline and a bypass pipeline, and the main pipeline is provided with a magnetic resonance flowmeter probe; when the magnetic resonance multiphase flowmeter operates in a flow measurement mode, the main pipeline is open and the bypass pipeline is closed; when the magnetic resonance multiphase flowmeter operates in a static measurement mode, the bypass pipeline is open and part of the produced fluid is statically closed in the main pipeline.

[0013] In some embodiments of the present application, the magnetic resonance multiphase flowmeter also includes a first three-way valve and a second three-way valve, wherein the first end of the first three-way valve is connected to one end of the main pipeline, the second end of the first three-way valve is connected to one end of the bypass pipeline, and the third end of the first three-way valve is connected to the inlet end of the magnetic resonance multiphase flowmeter; the first end of the second three-way valve is connected to the other end of the main pipeline, the second end of the second three-way valve is connected to the other end of the bypass pipeline, and the third end of the second three-way valve is connected to the outlet end of the magnetic resonance multiphase flowmeter.

[0014] In some embodiments of the present application, a temperature and pressure gauge is also provided on the main pipeline to measure the temperature and pressure of the produced fluid passing through the main pipeline.

[0015] In some embodiments of the present application, the method for detecting a horizontal well fluid production profile further includes:

[0016] B1. Obtain the geothermal gradient of the target mining site;

[0017] B2. Derivation of the temperature of the oil inlet end of the coiled tubing based on the temperature of the produced fluid measured by the thermometer and pressure gauge, the flow rate of the produced fluid and the geothermal gradient;

[0018] B3. Repeat steps B1 to B2 until the temperature of all layers in the horizontal well is measured;

[0019] B4. Match the temperature of each layer of the horizontal well with the measured depth and draw the temperature profile of the horizontal well;

[0020] B5. Obtaining a fluid production profile of the horizontal well under the influence of temperature based on the horizontal well temperature profile.

[0021] In some embodiments of the present application, the method for detecting a horizontal well fluid production profile further includes:

[0022] C1. Obtain the hydrostatic pressure of the vertical pipe section;

[0023] C2. Derivation of the pressure at the oil inlet end of the coiled tubing based on the pressure of the produced fluid measured by the temperature and pressure gauge and the hydrostatic pressure of the vertical pipe section;

[0024] C3, repeat steps C1 to C2 until the pressure measurement of all layers of the horizontal well is completed;

[0025] C4. Match the pressure of each layer of the horizontal well with the measured depth and draw the pressure profile of the horizontal well;

[0026] C5. Obtaining a fluid production profile of the horizontal well under the influence of pressure based on the horizontal well pressure profile.

[0027] In some embodiments of the present application, the horizontal well fluid production profile detection method further includes: determining the working time of the magnetic resonance multiphase flowmeter in the static measurement mode according to the variation cycle of the produced liquid phase content.

[0028] In some embodiments of the present application, the phase content includes water content; and the working time of the magnetic resonance multiphase flowmeter in the static measurement mode is not greater than 1 / 2 of the water content change period.

[0029] In some embodiments of the present application, the phase content includes oil content, gas content and water content; the calculation formula of the fluid production Q oil / gas / water is as follows:

[0030] Q 油 / 气 / 水 =πr 2 *v*S 油 / 气 / 水 (1)

[0031] In formula (1), Q oil / gas / water represents the oil production, gas production or water production, r represents the radius of the coiled tubing, and S oil / gas / water represents the oil content, gas content or water content of the produced fluid in the target layer.

[0032] This application has at least the following beneficial effects:

[0033] The present application utilizes a magnetic resonance multiphase flowmeter in conjunction with continuous tubing technology to complete the measurement of the horizontal well production profile at the wellhead, solving the problems of the existing production logging technology, such as high cost, unstable accuracy, and impact on production timeliness.

[0034] Other features and advantages of the embodiments of the present application will be described in detail in the subsequent specific implementation section. BRIEF DESCRIPTION OF THE DRAWINGS

[0035] The accompanying drawings are used to provide a further understanding of the embodiments of the present application and constitute a part of the specification. Together with the following specific implementations, they are used to explain the embodiments of the present application, but do not constitute a limitation on the embodiments of the present application. In the accompanying drawings:

[0036] Figure 1 The installation diagram of the magnetic resonance multiphase flowmeter according to the embodiment of the present application is schematically shown;

[0037] Figure 2 A schematic diagram of the internal structure of the magnetic resonance multiphase flowmeter structure of an embodiment of the present application is schematically shown;

[0038] Figure 3 A schematic diagram of a flow chart for measuring a production profile of a horizontal well in an embodiment of the present application is shown;

[0039] Figure 4 The fluid production profile of an example horizontal well according to an embodiment of the present application is schematically shown. DETAILED DESCRIPTION

[0040] In order to make the purpose, technical scheme and advantages of the embodiments of the present application clearer, the technical scheme in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. It should be understood that the specific implementation methods described herein are only used to illustrate and explain the embodiments of the present application, and are not used to limit the embodiments of the present application. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without making creative work are within the scope of protection of this application.

[0041] It should be noted that if the embodiments of the present application involve directional indications (such as up, down, left, right, front, back, etc.), such directional indications are only used to explain the relative position relationship, movement status, etc. between the components under a certain specific posture (as shown in the accompanying drawings). If the specific posture changes, the directional indication will also change accordingly.

[0042] In addition, if there are descriptions involving "first", "second", etc. in the embodiments of the present application, the descriptions of "first", "second", etc. are only used for descriptive purposes and cannot be understood as indicating or suggesting their relative importance or implicitly indicating the number of technical features indicated. Therefore, the features defined as "first" and "second" may explicitly or implicitly include at least one of the features. In addition, the technical solutions between the various embodiments can be combined with each other, but they must be based on the ability of ordinary technicians in the field to implement them. When the combination of technical solutions is contradictory or cannot be implemented, it should be deemed that such combination of technical solutions does not exist and is not within the scope of protection required by this application.

[0043] Example 1

[0044] A method for detecting a production profile of a horizontal well based on a magnetic resonance multiphase flowmeter, wherein the inlet end of the magnetic resonance multiphase flowmeter is connected to the oil outlet end of a coiled tubing through a well control device (blowout preventer or Christmas tree) at the wellhead (e.g. Figure 1 As shown in the figure, the outlet of the magnetic resonance multiphase flowmeter is connected to the external transmission pipeline, and the oil inlet of the coiled tubing is arranged in the target layer section of the horizontal well; that is, after the downhole production fluid flows to the wellhead through the coiled tubing, it directly flows through the multiphase flowmeter from the ground pipeline for measurement and testing, and then is transmitted to the outside through the external transmission pipeline.

[0045] The horizontal well production fluid profile detection method comprises:

[0046] A1. Use a magnetic resonance multiphase flowmeter to obtain the flow rate of the produced fluid in the target layer;

[0047] A2. Use a magnetic resonance multiphase flowmeter to obtain the phase content of the produced fluid in the target layer;

[0048] Specifically, the magnetic resonance multiphase flowmeter has two working modes: flow measurement mode and static measurement mode; the magnetic resonance multiphase flowmeter working in the flow measurement mode is used to measure the flow rate of the produced fluid, and the magnetic resonance multiphase flowmeter working in the static measurement mode is used to measure the phase content of the produced fluid.

[0049] The internal structure of the magnetic resonance multiphase flow meter is as follows: Figure 2As shown, the magnetic resonance multiphase flowmeter includes a main pipeline and a bypass pipeline, and the main pipeline is provided with a magnetic resonance flowmeter probe; when the magnetic resonance multiphase flowmeter works in the flow measurement mode, the main pipeline is open and the bypass pipeline is closed; when the magnetic resonance multiphase flowmeter works in the static measurement mode, the bypass pipeline is open and part of the produced liquid is statically closed in the main pipeline. The two ends of the main pipeline and the bypass pipeline are respectively connected by two three-way valves, namely the first three-way valve and the second three-way valve, wherein the first end of the first three-way valve is connected to one end of the main pipeline, the second end of the first three-way valve is connected to one end of the bypass pipeline, and the third end of the first three-way valve is connected to the inlet end of the magnetic resonance multiphase flowmeter; the first end of the second three-way valve is connected to the other end of the main pipeline, the second end of the second three-way valve is connected to the other end of the bypass pipeline, and the third end of the second three-way valve is connected to the outlet end of the magnetic resonance multiphase flowmeter.

[0050] A3. Calculate the fluid production of the target layer based on the flow rate, phase content and diameter of the coiled tubing of the produced fluid;

[0051] Specifically, the phase content includes oil content, gas content and water content; the fluid production Q 油 / 气 / 水 The calculation formula is as follows:

[0052] Q 油 / 气 / 水 =πr 2 *v*S 油 / 气 / 水 (1)

[0053] In formula (1), Q 油 / 气 / 水 represents oil production, gas production or water production, r represents the radius of the coiled tubing, S 油 / 气 / 水 Indicates the oil content, gas content or water content of the produced fluid in the target layer.

[0054] A4. Repeat steps A1 to A3 until the fluid production of all layers of the horizontal well is measured;

[0055] A5. Match the fluid production of each layer of the horizontal well with the measured depth and draw the horizontal well fluid production profile.

[0056] Combined with the wellhead well control device and the installation of magnetic resonance multiphase flowmeter, the specific drawing process of horizontal well production profile can be referred to Figure 3 The specific measurement process is as follows:

[0057] Before starting the measurement, the magnetic resonance equipment must be connected to the surface pipeline and switched to flow measurement mode (the main pipeline is open, the fluid can flow through the magnetic resonance probe, and the bypass pipeline is closed). After the bottom of the coiled tubing is lowered to the target layer, the measurement can begin.

[0058] After starting the measurement, first open the blowout preventer or Christmas tree to allow the downhole fluid to flow into the magnetic resonance multiphase flowmeter through the coiled tubing, blowout preventer or Christmas tree, and then flow into the surface manifold for further processing.

[0059] The magnetic resonance multiphase flowmeter first collects the temperature, pressure, and flow rate information of the downhole production fluid in real time in the flow measurement mode, and then switches to the static measurement mode after a period of time (the fluid in the probe is stationary, and the downhole production fluid flows into the surface manifold through the bypass of the magnetic resonance multiphase flowmeter). In the static measurement mode, the magnetic resonance multiphase flowmeter will be used to detect the phase content (water content, gas content, oil content), viscosity distribution, relaxation time, gravity and other multiphase flow properties of the multiphase flow. Among them, the duration of the static measurement mode is determined according to the change cycle of the produced liquid phase content. Usually, the working time of the magnetic resonance multiphase flowmeter in the static measurement mode is not more than 1 / 2 of the water content change cycle, which conforms to the sampling law (that is, the sampling frequency is not less than 2 times the periodic change frequency of the measured parameter). Since the working mode of the magnetic resonance multiphase flowmeter is switched between static measurement and flow measurement, when the duration of the static measurement mode is determined, the duration of the flow measurement mode is also determined.

[0060] Based on the flow rate information and phase content information collected in the dynamic and static modes, the flow rates of oil, gas, and water phases can be derived. The specific method is flow rate Q oil / gas / water = πr2*v*S oil / gas / water, where r is the radius of the pipeline, v is the flow rate, and S is the phase content. Usually, the dynamic and static modes are switched repeatedly. After the static mode is measured once, it is switched to the dynamic mode for cyclic measurement for a period of time. The measurement interval of the static mode is determined by the frequency of change of the fluid phase content. If the phase content change cycle is long, the measurement interval of the static mode can be set longer. The measurement frequency of the dynamic mode generally uses the maximum frequency acceptable to the flowmeter to continuously monitor the fluid flow rate.

[0061] After monitoring of one layer section is completed, the valve connecting the wellhead blowout preventer or the Christmas tree to the multiphase flowmeter is closed, the coiled tubing drum rotates, and the bottom of the coiled tubing is dragged to move to the second measurement section. After the above measurement steps are repeated, the measurement of the second measurement section is completed.

[0062] Repeat the above steps until all horizontal well sections are measured, and the flow rate, fluid properties, temperature and pressure data of each layer can be obtained to draw the fluid production profile (such as Figure 4 shown).

[0063] After the production profile test is completed, the multiphase flowmeter can be kept at the wellhead as required to enter production measurement.

[0064] Preferably, the horizontal well production profile detection method further includes:

[0065] B1. Obtain the geothermal gradient of the target mining site;

[0066] B2. Derivation of the temperature of the oil inlet end of the coiled tubing based on the temperature of the produced fluid measured by the thermometer and pressure gauge, the flow rate of the produced fluid and the geothermal gradient;

[0067] B3. Repeat steps B1 to B2 until the temperature of all layers in the horizontal well is measured;

[0068] B4. Match the temperature of each layer of the horizontal well with the measured depth and draw the temperature profile of the horizontal well;

[0069] B5. Obtaining a fluid production profile of the horizontal well under the influence of temperature based on the horizontal well temperature profile.

[0070] Temperature is also a factor that affects the calculation of liquid production. The liquid production profile of a horizontal well calculated by considering the temperature effect is more accurate. For example, taking a steam-assisted gravity drainage (SAGD) well as an example, the temperature distribution of the horizontal section of the production well is basically consistent with the liquid production distribution. The high-temperature distribution section of the horizontal well indicates that the high-temperature steam has penetrated smoothly here, achieving viscosity reduction and oil drainage, that is, the liquid production of this section is usually higher. Therefore, the temperature profile can in some cases prove whether the obtained liquid production profile is accurate.

[0071] Preferably, the horizontal well production profile detection method further includes:

[0072] C1. Obtain the hydrostatic pressure of the vertical pipe section;

[0073] C2. Derivation of the pressure at the oil inlet end of the coiled tubing based on the pressure of the produced fluid measured by the temperature and pressure gauge and the hydrostatic pressure of the vertical pipe section;

[0074] C3, repeat steps C1 to C2 until the pressure measurement of all layers of the horizontal well is completed;

[0075] C4. Match the pressure of each layer of the horizontal well with the measured depth and draw the pressure profile of the horizontal well;

[0076] C5. Obtaining a fluid production profile of the horizontal well under the influence of pressure based on the horizontal well pressure profile.

[0077] Pressure is also a factor that affects the calculation of liquid production. The horizontal well production profile calculated by considering the influence of pressure is more accurate. Preferably, the pressure at the oil inlet end of the coiled tubing can also be further considered by the pressure loss of the horizontal section to improve the accuracy of the calculation. Specifically, the pressure loss of the horizontal section consists of four parts: friction pressure loss, acceleration pressure loss, mixed pressure loss, and potential pressure loss. In addition, since the gas phase is more affected by pressure among the three phases of oil, gas, and water, the acquisition of the pressure profile can greatly improve the accuracy of the calculation of the gas content in each section of the produced liquid.

[0078] It should also be noted that the terms "include", "comprises" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, commodity or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, commodity or device. In the absence of more restrictions, the elements defined by the sentence "comprises a ..." do not exclude the existence of other identical elements in the process, method, commodity or device including the elements.

[0079] The above are only embodiments of the present application and are not intended to limit the present application. For those skilled in the art, the present application may have various changes and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included within the scope of the claims of the present application.

Claims

1. A method for detecting a production profile of a horizontal well based on a magnetic resonance multiphase flowmeter, wherein the inlet end of the magnetic resonance multiphase flowmeter is connected to the oil outlet end of a coiled tubing through a well control device at a wellhead, the outlet end of the magnetic resonance multiphase flowmeter is connected to an external transmission pipeline, and the oil inlet end of the coiled tubing is arranged at a target layer section of the horizontal well; characterized in that: The horizontal well production fluid profile detection method comprises: A1. Use a magnetic resonance multiphase flowmeter to obtain the flow rate of the produced fluid in the target layer; A2. Use a magnetic resonance multiphase flowmeter to obtain the phase content of the produced fluid in the target layer; A3. Calculate the fluid production of the target layer based on the flow rate, phase content and diameter of the coiled tubing of the produced fluid; A4. Repeat steps A1 to A3 until the fluid production of all layers of the horizontal well is measured; A5. Match the fluid production of each layer of the horizontal well with the measured depth and draw the horizontal well fluid production profile.

2. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 1, characterized in that: The magnetic resonance multiphase flowmeter has two working modes: Flow measurement mode, used to measure the flow rate of produced fluid; Static measurement mode is used to measure the phase content of produced fluid.

3. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 2, characterized in that: The magnetic resonance multiphase flowmeter comprises a main pipeline and a bypass pipeline, and a magnetic resonance flowmeter probe is arranged on the main pipeline; When the magnetic resonance multiphase flowmeter operates in the flow measurement mode, the main pipeline is open and the bypass pipeline is closed; When the magnetic resonance multiphase flowmeter operates in a static measurement mode, the pipeline passage is bypassed and part of the produced fluid is statically sealed in the main pipeline.

4. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 3, characterized in that: The magnetic resonance multiphase flowmeter also includes a first three-way valve and a second three-way valve; The first end of the first three-way valve is connected to one end of the main pipeline, the second end of the first three-way valve is connected to one end of the bypass pipeline, and the third end of the first three-way valve is connected to the inlet end of the magnetic resonance multiphase flowmeter; The first end of the second three-way valve is communicated with the other end of the main pipeline, the second end of the second three-way valve is communicated with the other end of the bypass pipeline, and the third end of the second three-way valve is connected to the outlet end of the magnetic resonance multiphase flowmeter.

5. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 3, characterized in that: The main pipeline is also provided with a temperature and pressure gauge for measuring the temperature and pressure of the produced fluid passing through the main pipeline.

6. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 5, characterized in that: The horizontal well production fluid profile detection method also includes: B1. Obtain the geothermal gradient of the target mining site; B2. Obtaining the temperature of the oil inlet end of the coiled tubing based on the temperature of the produced fluid, the flow rate of the produced fluid and the geothermal gradient measured by the thermometer and pressure gauge; B3. Repeat steps B1 to B2 until the temperature of all layers in the horizontal well is measured; B4. Match the temperature of each layer of the horizontal well with the measured depth and draw the temperature profile of the horizontal well; B5. Obtaining a fluid production profile of the horizontal well under the influence of temperature based on the horizontal well temperature profile.

7. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 5, characterized in that: The horizontal well production fluid profile detection method also includes: C1. Obtain the hydrostatic pressure of the vertical pipe section; C2. Based on the pressure of the produced fluid measured by the temperature and pressure gauge and the hydrostatic pressure of the vertical pipe section, deduce the pressure at the oil inlet end of the coiled tubing; C3, repeat steps C1 to C2 until the pressure measurement of all layers of the horizontal well is completed; C4. Match the pressure of each layer of the horizontal well with the measured depth and draw the pressure profile of the horizontal well; C5. Obtaining a fluid production profile of the horizontal well under the influence of pressure based on the horizontal well pressure profile.

8. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 5, characterized in that: The horizontal well production fluid profile detection method also includes: The working time of the magnetic resonance multiphase flowmeter in the static measurement mode is determined according to the variation cycle of the produced liquid phase content.

9. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 8, characterized in that: The phase content includes water content; the working time of the magnetic resonance multiphase flowmeter in the static measurement mode is not greater than 1 / 2 of the water content change period.

10. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 1, characterized in that: The phase content includes oil content, gas content and water content; the fluid production Q 油 / 气 / 水 The calculation formula is as follows: Q 油 / 气 / 水 =πr 2 *v*S 油 / 气 / 水 (1) In formula (1), Q 油 / 气 / 水 represents oil production, gas production or water production, r represents the radius of the coiled tubing, S 油 / 气 / 水 Indicates the oil content, gas content or water content of the produced fluid in the target layer.

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