Method for detecting horizontal well fluid production profile based on magnetic resonance multiphase flowmeter

Abstract

The application 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. An inlet end of the magnetic resonance multiphase flowmeter is connected with an oil outlet end of a coiled tubing through well control devices of a well head, an outlet end of the magnetic resonance multiphase flowmeter is connected with an external transport pipeline, and an oil inlet end of the coiled tubing is arranged in a target layer section of a horizontal well. The method comprises the following steps: obtaining the flow rate of produced liquid of the target layer section by using the magnetic resonance multiphase flowmeter; obtaining the phase content rate of the produced liquid of the target layer section by using the magnetic resonance multiphase flowmeter; calculating the fluid production of the target layer section based on the flow rate, the phase content rate and the pipe diameter of the coiled tubing; repeating the above steps until the measurement of the fluid production of all layer sections of the horizontal well is completed; matching the fluid production of each layer section of the horizontal well with the measured depth, and drawing the horizontal well liquid production profile. The method can solve the problems of high cost, unstable precision and influence on production timeliness of the current production logging technology.

Description

TECHNICAL FIELD

[0001] The present application 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. BACKGROUND

[0002] Horizontal wells can increase the productivity of oil and gas wells, are suitable for the exploitation of low-permeability, low-pressure, heavy oil and other types of reservoirs, and can achieve high production of sparse wells. In recent years, the number of horizontal wells drilled at home and abroad has increased year by year. For the production dynamic evaluation of horizontal wells, especially for the monitoring of the segmented production of each fracturing section of the horizontal well and the main production layer, the design, modification and production management of future horizontal wells become more and more important. Although the existing production logging technical means can basically meet the production needs for the production dynamic evaluation of vertical wells, these technologies cannot completely solve the problems in horizontal wells when applied to horizontal wells. For example, in the horizontal well completed with a slotted liner, the annular space between the slotted liner and the formation is prone to flow around, causing the logging instrument to be unsuitable or even fail. In addition, due to the oil and gas water separation problem of the fluid in the wellbore under the action of gravity, the flow pattern of the mixed fluid is complex and variable, and combined with the long-distance undulating of the horizontal wellbore, the horizontal flow production profile is abnormally complex, which brings great difficulty to the evaluation of the production dynamic of such oil and gas wells by production logging technical means, and it is difficult to solve the flow distribution problem of the fluid in the entire horizontal well section and a series of problems such as the flow entry point of oil and gas, 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 in-depth development of unconventional oil and gas resources, the underground fluid in the field of petroleum drilling and production engineering is mainly oil and water two-phase mixed fluid. Among them, shale oil and heavy oil as important unconventional oil and gas resources have very serious emulsification phenomenon, and are in the state of oil-in-water and water-in-oil in the pipeline for a long time. Combined with the problem of sand production downhole, it brings great difficulty to oil and gas metering and testing, and the conventional production logging means cannot effectively measure the oil and gas water three-phase production of each section of the horizontal well. SUMMARY

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

[0005] In order to achieve the above-mentioned purpose, the present application provides 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 the coiled tubing through the well control device of the wellhead, the outlet end of the magnetic resonance multiphase flowmeter is connected with the external transport pipeline, and the oil inlet end of the coiled tubing is arranged in the target layer section of the horizontal well; the horizontal well liquid production profile detection method comprises the following steps:

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

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

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

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

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

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

[0012] In some embodiments of this application, the magnetic resonance multiphase flow meter includes a main pipeline and a bypass pipeline, and a magnetic resonance flow meter probe is provided on the main pipeline; when the magnetic resonance multiphase flow meter is operating in flow measurement mode, the main pipeline is open and the bypass pipeline is closed; when the magnetic resonance multiphase flow meter is operating in static measurement mode, the bypass pipeline is open and part of the collected liquid is statically sealed in the main pipeline.

[0013] In some embodiments of this application, the magnetic resonance multiphase flow meter further 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 flow meter. 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 flow meter.

[0014] In some embodiments of this application, the main pipeline is also equipped with a thermo-pressure gauge for measuring the temperature and pressure of the extracted fluid passing through the main pipeline.

[0015] In some embodiments of this application, the horizontal well production profile detection method further includes:

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

[0017] B2. Based on the temperature of the produced fluid, the flow rate of the produced fluid, and the geothermal gradient measured by the thermobarometer, derive the temperature at the inlet end of the coiled tubing.

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

[0019] B4. Match the temperature of each section of the horizontal well with the measurement depth, and draw the temperature profile of the horizontal well.

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

[0021] In some embodiments of this application, the horizontal well production profile detection method further includes:

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

[0023] C2. Derive the pressure at the inlet of the coiled tubing based on the pressure of the produced fluid measured by the thermo-barometer and the hydrostatic pressure of the vertical tubing section.

[0024] C3. Repeat steps C1 to C2 until the pressure measurement of all sections of the horizontal well is completed;

[0025] C4. Match the pressure of each section of the horizontal well with the measurement depth, and draw the pressure profile of the horizontal well.

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

[0027] In some embodiments of this application, the method for detecting the production profile of a horizontal well further includes: determining the working time of the magnetic resonance multiphase flowmeter in static measurement mode based on the cycle of change in the produced liquid phase content.

[0028] In some embodiments of this application, the phase content includes the water content; the working time of the magnetic resonance multiphase flowmeter in static measurement mode is no more than 1 / 2 of the water content change cycle.

[0029] In some embodiments of this application, the phase content includes oil content, gas content, and water content; the formula for calculating the fluid production rate 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 formation.

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

[0033] This application utilizes a magnetic resonance multiphase flowmeter in conjunction with coiled tubing technology to complete the production profile measurement of horizontal wells at the wellhead, solving the problems of high cost, unstable accuracy, and impact on production efficiency of existing production logging technologies.

[0034] Other features and advantages of the embodiments of this application will be described in detail in the following detailed description section. Attached Figure Description

[0035] The accompanying drawings are provided to further illustrate the embodiments of this application and form part of the specification. They are used together with the following detailed description to explain the embodiments of this application, but do not constitute a limitation on the embodiments of this application. In the drawings:

[0036] Figure 1 The schematic diagram illustrates the installation of a magnetic resonance multiphase flow meter according to an embodiment of this application;

[0037] Figure 2 This illustration schematically shows the internal structure of a magnetic resonance multiphase flowmeter according to an embodiment of this application.

[0038] Figure 3 This illustration schematically shows a flowchart of horizontal well production profile measurement according to an embodiment of this application;

[0039] Figure 4 An example horizontal well production profile of an embodiment of this application is illustrated schematically. Detailed Implementation

[0040] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only for illustration and explanation of the embodiments of this application and are not intended to limit the embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without creative effort are within the scope of protection of this application.

[0041] It should be noted that if the embodiments of this application involve directional indicators (such as up, down, left, right, front, back, etc.), the directional indicators are only used to explain the relative positional relationship and movement of the components in a certain specific posture (as shown in the figure). If the specific posture changes, the directional indicators will also change accordingly.

[0042] Furthermore, if the embodiments of this application involve descriptions such as "first" or "second," these descriptions are for descriptive purposes only and should not be construed as indicating or implying their relative importance or implicitly specifying the number of technical features indicated. Therefore, features defined with "first" or "second" may explicitly or implicitly include at least one of those features. Additionally, the technical solutions of various embodiments can be combined with each other, but this must be based on the ability of those skilled in the art to implement them. If the combination of technical solutions is contradictory or impossible to implement, it should be considered that such a combination of technical solutions does not exist and is not within the scope of protection claimed in this application.

[0043] Example 1

[0044] A method for detecting the production profile of horizontal wells 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 the coiled tubing via a well control device (blowout preventer or Christmas tree) at the wellhead (e.g., Figure 1 As shown), the outlet end of the magnetic resonance multiphase flowmeter is connected to the external transmission pipeline, and the inlet end of the coiled tubing is located in the target layer of the horizontal well; that is, after the downhole produced fluid flows to the wellhead through the coiled tubing, it flows directly through the surface pipeline to the multiphase flowmeter for measurement and analysis, and then is transmitted externally through the external transmission pipeline.

[0045] The method for detecting the production profile of horizontal wells includes:

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

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

[0048] Specifically, the magnetic resonance multiphase flow meter has two operating modes: flow measurement mode and static measurement mode. The magnetic resonance multiphase flow meter operating in flow measurement mode is used to measure the flow velocity of the produced fluid, while the magnetic resonance multiphase flow meter operating in static measurement mode is used to measure the phase content of the produced fluid.

[0049] The internal structure of a magnetic resonance multiphase flow meter is as follows: Figure 2As shown, the magnetic resonance multiphase flow meter includes a main pipeline and a bypass pipeline. A magnetic resonance flow meter probe is installed on the main pipeline. When the magnetic resonance multiphase flow meter operates in flow measurement mode, the main pipeline is open, and the bypass pipeline is closed. When the magnetic resonance multiphase flow meter operates in static measurement mode, the bypass pipeline is open, and part of the collected fluid is statically contained within the main pipeline. The two ends of the main pipeline and the bypass pipeline are connected by two three-way valves, namely 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 flow meter. 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 flow meter.

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

[0051] Specifically, the phase content includes oil content, gas content, and water content; the fluid production rate 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 equation (1), Q 油 / 气 / 水 Indicates oil production, gas production, or water production; r represents the radius of the coiled tubing; S 油 / 气 / 水 This indicates the oil content, gas content, or water content of the produced fluid in the target formation.

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

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

[0056] The detailed process for drawing the production profile of a horizontal well, in conjunction with the installation of the wellhead control equipment and the magnetic resonance multiphase flow meter, can be found in [reference needed]. Figure 3 As shown. The specific measurement process is as follows:

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

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

[0059] The magnetic resonance multiphase flowmeter first acquires real-time data on the temperature, pressure, and velocity of the produced fluid in the wellbore in flow measurement mode. After a period of time, it switches to static measurement mode (the fluid inside the probe is stationary, and the produced fluid flows into the surface manifold through a bypass of the magnetic resonance multiphase flowmeter). In static measurement mode, the magnetic resonance multiphase flowmeter is used to detect the phase content (water content, gas content, oil content), viscosity distribution, relaxation time, and density of the multiphase flow, among other fluid properties. The duration of the static measurement mode is determined based on the period of change in the produced fluid's phase content. Typically, the operating time of the magnetic resonance multiphase flowmeter in static measurement mode is no more than half the period of change in water content, conforming to the sampling law (i.e., the sampling frequency is no less than twice the periodic change frequency of the measured parameter). Since the magnetic resonance multiphase flowmeter switches between static and flow measurement modes, the duration of the flow measurement mode is also determined when the duration of the static measurement mode is fixed.

[0060] Based on the flow velocity and phase inclusion information collected in both static and dynamic modes, the flow rates of oil, gas, and water can be derived. Specifically, the flow rate Qoil / gas / water = πr2 * v * Soil / gas / water, where r is the pipe radius, v is the flow velocity, and S is the phase inclusion. Typically, the static and dynamic modes are switched repeatedly. Generally, after one measurement in static mode, the flow is switched to dynamic mode for a period of time. The measurement interval in static mode depends on the frequency of change in the fluid phase inclusion. If the phase inclusion change period is long, the measurement interval in static mode can be set to be longer. The measurement frequency in dynamic mode is generally the maximum acceptable frequency of the flow meter, continuously monitoring the fluid flow velocity.

[0061] After monitoring of one section is completed, close the valve connecting the wellhead blowout preventer or the Christmas tree to the multiphase flow meter, rotate the coiled tubing drum, and drag the bottom of the coiled tubing to the second measurement section. Repeat the above measurement steps to complete the measurement of the second measurement section.

[0062] Repeat the above steps until all horizontal well sections are measured. This will allow you to obtain flow rate, fluid properties, and temperature / pressure data for each section, enabling the creation of a production profile (e.g., ...). Figure 4 (As shown).

[0063] After the production profile test is completed, the multiphase flow meter can be left at the wellhead for production metering as needed.

[0064] Preferably, the method for detecting the production profile of a horizontal well further includes:

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

[0066] B2. Based on the temperature of the produced fluid, the flow rate of the produced fluid, and the geothermal gradient measured by the thermobarometer, derive the temperature at the inlet end of the coiled tubing.

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

[0068] B4. Match the temperature of each section of the horizontal well with the measurement depth, and draw the temperature profile of the horizontal well.

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

[0070] Temperature is also a factor affecting production calculations, and considering the effect of temperature leads to more accurate production profiles for horizontal wells. For example, in a steam-assisted gravity drainage (SAGD) well, the temperature distribution in the horizontal section of the production well is basically consistent with the production distribution. The high-temperature distribution section in the horizontal well indicates that high-temperature steam has successfully penetrated this area, achieving viscosity reduction and drainage; that is, the production rate in this section is usually higher. Therefore, temperature profiles can, in some cases, corroborate the accuracy of the obtained production profile.

[0071] Preferably, the method for detecting the production profile of a horizontal well further includes:

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

[0073] C2. Derive the pressure at the inlet of the coiled tubing based on the pressure of the produced fluid measured by the thermo-barometer and the hydrostatic pressure of the vertical tubing section.

[0074] C3. Repeat steps C1 to C2 until the pressure measurement of all sections of the horizontal well is completed;

[0075] C4. Match the pressure of each section of the horizontal well with the measurement depth, and draw the pressure profile of the horizontal well.

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

[0077] Pressure is also a factor affecting production calculations; considering the impact of pressure leads to more accurate production profiles for horizontal wells. Preferably, the pressure at the inlet of the coiled tubing can be further improved by considering the pressure loss in the horizontal section. Specifically, the pressure loss in the horizontal section consists of four parts: frictional pressure loss, acceleration pressure loss, mixing pressure loss, and potential energy pressure loss. Furthermore, since the gas phase is most significantly affected by pressure among the oil, gas, and water phases, obtaining the pressure profile can greatly improve the accuracy of calculating the gas content in the produced fluid at each stage.

[0078] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0079] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A method for detecting the 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 the coiled tubing via a well control device at the wellhead, the outlet end of the magnetic resonance multiphase flowmeter is connected to an external pipeline, and the oil inlet end of the coiled tubing is located in the target formation of the horizontal well; characterized in that, The method for detecting the production profile of horizontal wells includes: A1. Use a magnetic resonance multiphase flow meter to obtain the flow rate of the produced fluid in the target layer; A2. Use a magnetic resonance multiphase flow meter to obtain the phase content of the produced fluid in the target layer; A3. Calculate the fluid production rate of the target formation based on the produced fluid velocity, phase content, and the diameter of the coiled tubing. A4. Repeat steps A1 to A3 until the fluid production of all sections of the horizontal well is measured. A5. Match the fluid production of each section of the horizontal well with the measurement depth and draw the fluid production profile of the horizontal well; The method further includes: C1. Obtain the hydrostatic pressure of the vertical pipe section; C2. Based on the pressure of the produced fluid measured by the thermo-barometer and the hydrostatic pressure of the vertical pipe section, derive the pressure at the oil inlet of the coiled tubing. C3. Repeat steps C1 to C2 until the pressure measurement of all sections of the horizontal well is completed; C4. Match the pressure of each section of the horizontal well with the measurement depth, and draw the pressure profile of the horizontal well. C5. Obtain the horizontal well production profile under the influence of pressure based on the horizontal well pressure 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 flow meter has two operating modes: Flow measurement mode, used to measure the flow rate of the produced fluid; The static measurement mode is used to measure the phase content of the 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 flow meter includes a main pipeline and a bypass pipeline, and a magnetic resonance flow meter probe is installed on the main pipeline; When the magnetic resonance multiphase flowmeter is operating in flow measurement mode, the main pipeline is open and the bypass pipeline is closed. When the magnetic resonance multiphase flowmeter operates in static measurement mode, the bypass pipeline is open, and part of the extracted fluid is statically sealed within 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 flow meter 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 flow meter. 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 flow meter.

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 equipped with a temperature and pressure gauge to measure the temperature and pressure of the extracted 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 method for detecting fluid production profiles in horizontal wells also includes: B1. Obtain the geothermal gradient of the target mining site; B2. Based on the temperature of the produced fluid, the flow rate of the produced fluid, and the geothermal gradient measured by the thermobarometer, obtain the temperature at the inlet end of the coiled tubing. B3. Repeat steps B1 to B2 until the temperature of all sections of the horizontal well is measured. B4. Match the temperature of each section of the horizontal well with the measurement depth, and draw the temperature profile of the horizontal well. B5. Obtain the 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 method for detecting fluid production profiles in horizontal wells also includes: The operating time of the magnetic resonance multiphase flowmeter in static measurement mode is determined based on the cycle of change in the extracted liquid phase content.

8. The method for detecting the production profile of a horizontal well based on a magnetic resonance multiphase flowmeter according to claim 7, characterized in that, The phase content includes the water content; the working time of the magnetic resonance multiphase flow meter in static measurement mode is no more than 1 / 2 of the water content change cycle.

9. 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 rate Q 油 / 气 / 水 The calculation formula is as follows: Q 油 / 气 / 水 =πr 2 *v*S 油 / 气 / 水 (1) In equation (1), Q 油 / 气 / 水 Indicates oil production, gas production, or water production; r represents the radius of the coiled tubing; S 油 / 气 / 水 This indicates the oil content, gas content, or water content of the produced fluid in the target formation.

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