CN114592802A - Method, device, equipment and storage medium for determining the service conditions of insulated oil pipes - Google Patents

Abstract

The present application provides a method, device, equipment and storage medium for determining the service conditions of an insulated oil pipe. In this method, according to the pre-obtained inlet pressure and liquid/gas production volume, the preset calculation model is respectively input to obtain the apparent thermal conductivity of the insulated oil pipe. Then, based on the apparent thermal conductivity, the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness of the thermal insulation tubing is the first thermal insulation thickness, and the wellhead temperatures when the thermal thermal insulation thickness of the thermal thermal insulation pipeline is the second thermal insulation thickness are obtained respectively. Wellhead temperatures corresponding to multiple tubing lengths. Finally, according to the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the first insulation thickness, and the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the second insulation thickness, the use conditions of the insulated tubing are determined . In this method, the use conditions of the thermal insulation oil pipe are determined by comparing the thermal insulation oil pipes with different thermal insulation thicknesses.

Description

Method, device, equipment and storage medium for determining the service conditions of insulated oil pipes

technical field

The present application relates to the technical field of exploration and development, and in particular, to a method, device, equipment and storage medium for determining the service conditions of an insulated oil pipe.

Background technique

In recent years, the phenomenon of wellbore wax plugging has been discovered in the process of oilfield exploitation, which leads to the gradual reduction of wellbore flow channels, which increases the frictional resistance of oil flow, which not only reduces productivity, but may also cause well shut-in and production shutdown. Wellbore wax plugging is mainly due to the fact that the temperature of the oil is too low, which causes the paraffin molecules in the oil to crystallize and precipitate, thereby causing the phenomenon of wax plugging.

In the prior art, for wellbore wax plugging, mechanical wax removal is generally adopted, that is, a special wax removal tool is used to scrape off the paraffin on the pipe wall. However, this technical solution has problems such as low wax removal efficiency, high cost of labor and auxiliary tools, and many secondary accidents during construction. In view of this, it can be considered to run an insulated tubing in the wellbore, that is, to reduce the heat loss of the oil during the wellbore flow through the insulated tubing, so as to prevent the crystallization and precipitation of paraffin molecules in the oil. This method can effectively Avoid the many problems that mechanical wax removal can cause.

However, in the actual use of thermal insulation tubing, it is necessary to consider the use conditions of thermal insulation tubing. Unreasonable use of thermal insulation tubing will still lead to the phenomenon of wellbore wax plugging in oil wells, or/and insignificant increase in productivity, resulting in material waste. And other issues.

SUMMARY OF THE INVENTION

The present application provides a method, device, equipment and storage medium for determining the use conditions of an insulated oil pipe, so as to realize the determination of the use conditions of an insulated oil pipe.

In a first aspect, an embodiment of the present application provides a method for determining the service conditions of an insulated oil pipe, including:

According to the pre-obtained inlet pressure and liquid/gas production volume, the preset calculation models are respectively input to obtain the apparent thermal conductivity of the insulating oil pipe, where the apparent thermal conductivity is used to represent the relationship between the thickness of the thermal insulating material and the thermal conductivity , the calculation model is used to calculate the apparent thermal conductivity of the insulated oil pipe;

According to the apparent thermal conductivity, respectively acquiring the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness;

According to the apparent thermal conductivity, respectively acquiring the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness;

According to the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness, and the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the second thermal insulation thickness, the interval is determined. Conditions of use for hot oil pipes, including the range of depths of oil wells.

In a possible design of the first aspect, the method further includes:

Obtain the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths;

According to the mapping relationship, the liquid production volume range for the use of the insulated oil pipe is determined, wherein the use condition further includes the liquid production volume range.

In this possible design, the method further includes:

For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes that are less than the preset value;

According to the wellhead temperature of the insulated oil pipe and the wellhead temperature of the common oil pipe corresponding to each liquid production amount, the mapping relationship between the liquid production amount and the wellhead temperature rise value of the insulated oil pipe is determined.

Optionally, the thermal insulation oil pipe includes: a vacuum thermal insulation oil pipe and an aerogel thermal insulation oil pipe.

In a second aspect, the present application provides a device for determining the service conditions of an insulated oil pipe, comprising: a processing module and a determination module;

The processing module is configured to input a preset calculation model according to the pre-acquired inlet pressure and liquid/gas production volume, respectively, to obtain the apparent thermal conductivity of the insulating oil pipe, where the apparent thermal conductivity is used to represent the thickness of the thermal insulating material The relationship between the thermal conductivity and the thermal conductivity, the calculation model is used to calculate the apparent thermal conductivity of the insulated oil pipe;

The processing module is further configured to obtain, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness;

The processing module is further configured to acquire, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness;

The determining module is used for wellhead temperatures corresponding to a plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness, and a plurality of tubing lengths corresponding to the thermal insulating thickness when the second thermal insulation thickness is the second thermal insulation thickness. The wellhead temperature determines the use conditions of the insulated oil pipe, and the use conditions include the depth range of the oil well.

In a possible design of the second aspect, the processing module is further configured to:

Obtain the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths;

According to the mapping relationship, the liquid production volume range for the use of the insulated oil pipe is determined, wherein the use condition further includes the liquid production volume range.

In this possible design, the processing module is also used for:

For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes that are less than the preset value;

According to the wellhead temperature of the insulated oil pipe and the wellhead temperature of the common oil pipe corresponding to each liquid production amount, the mapping relationship between the liquid production amount and the wellhead temperature rise value of the insulated oil pipe is determined.

Optionally, the thermal insulation oil pipe includes: a vacuum thermal insulation oil pipe and an aerogel thermal insulation oil pipe.

In a third aspect, an embodiment of the present application provides a computer device, including: a processor, a memory, and a display;

the memory for storing computer program instructions executable on the processor;

The processor, when executing the computer program instructions, implements the methods provided by the first aspect and possible designs described above.

In a fourth aspect, embodiments of the present application may provide a computer-readable storage medium, where computer-executable instructions are stored in the computer-readable storage medium, and when the computer-executable instructions are executed by a processor, are used to implement the first aspect and methods provided by each possible design.

In a fifth aspect, an embodiment of the present application provides a program for executing the method according to the first aspect when the program is executed by a processor.

In a sixth aspect, embodiments of the present application provide a computer program product, including program instructions, where the program instructions are used to implement the method described in the first aspect.

The embodiments of the present application provide a method, device, equipment, and storage medium for determining the use conditions of an insulated oil pipe. In this method, according to the pre-obtained inlet pressure and liquid/gas production volume, the preset calculation models are respectively input to obtain the apparent thermal conductivity of the thermal insulation oil pipe. Based on the apparent thermal conductivity, the thermal insulation thickness of the thermal insulation oil pipe is obtained as the first The wellhead temperatures corresponding to the lengths of the plurality of tubing when the thermal insulation thickness is one, and the wellhead temperatures corresponding to the lengths of the tubing when the thermal insulation thickness of the insulated tubing is the second thermal insulation thickness. Finally, according to the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the first insulation thickness, and the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the second insulation thickness, the use conditions of the insulated tubing are determined . In this method, the use conditions of the thermal insulation oil pipes are determined by comparing the thermal insulation oil pipes with different thermal insulation thicknesses.

Description of drawings

1 is a flowchart of Embodiment 1 of a method for determining the service conditions of an insulated oil pipe provided by an embodiment of the present application;

2A is a schematic diagram of a computing model interface provided by an embodiment of the present application;

FIG. 2B is a schematic diagram of the variation curve of wellbore flow temperature with depth according to an embodiment of the present application;

3 is a schematic diagram of wellhead temperatures corresponding to different tubing lengths when the first thermal insulation thickness is provided in the embodiment of the present application;

4 is a schematic diagram of wellhead temperatures corresponding to different tubing lengths when the second thermal insulation thickness is provided in the embodiment of the present application;

5 is a flowchart of Embodiment 2 of a method for determining the service conditions of an insulated oil pipe provided by an embodiment of the present application;

6 is a schematic diagram of a mapping relationship of wellhead temperature rise values corresponding to different tubing lengths according to an embodiment of the present application;

FIG. 7 is a flowchart of Embodiment 3 of the method for determining the service conditions of an insulated oil pipe provided by the embodiment of the present application;

FIG. 8 is a schematic diagram of the mapping relationship of the wellhead temperature rise value corresponding to the low liquid production volume provided by the embodiment of the present application;

9 is a schematic structural diagram of a device for determining the service conditions of an insulated oil pipe provided by an embodiment of the present application;

FIG. 10 is a schematic structural diagram of a computer device provided by an embodiment of the present application.

Detailed ways

In order to make the purposes, technical solutions and advantages of the embodiments of the present application clearer, the technical solutions in the embodiments of the present application will be described clearly and completely below with reference to the drawings in the embodiments of the present application. Obviously, the described embodiments It is a part of the embodiments of the present application, but not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative efforts shall fall within the protection scope of the present application.

The terms "first", "second", etc. (if present) in the description and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects and are not necessarily used to describe a particular order or sequence. It is to be understood that the data so used may be interchanged under appropriate circumstances such that the embodiments of the invention described herein can be practiced in sequences other than those illustrated or described herein. Furthermore, the terms "comprising" and "having", and any variations thereof, are intended to cover non-exclusive inclusion, for example, a process, method, product or apparatus comprising a series of steps or units is not necessarily limited to those steps expressly listed or units, but may include other steps or units not expressly listed or inherent to these processes, methods, products or devices.

Before introducing the embodiments of the present application, the background technology of the present application is explained first.

In recent years, in the production process of some oilfields, serious wellbore wax plugging has occurred. After wax deposition in oil and gas wells, the flow channel of the wellbore is gradually reduced, which increases the frictional resistance of oil and gas flow, which not only reduces the production capacity, but also may cause the problem of shut-in and production stoppage.

Wellbore waxing is a common problem faced by many oilfields. For wellbore wax plugging, domestic and foreign scholars have proposed a variety of mechanical wax removal techniques. However, these wax removal processes have problems such as low wax removal efficiency, high cost, and many secondary construction accidents. In view of this, it can be considered to add an insulating oil pipe to reduce the heat loss of the oil flow during the flow of the oil well, so that the residual temperature in the oil well can prevent the crystallization and precipitation of paraffin molecules. However, when using thermal insulation tubing in practice, it is necessary to consider the usage conditions of thermal insulation tubing, otherwise it will still lead to wellbore wax plugging after using thermal insulation tubing, or/and insignificant increase in productivity, resulting in material waste and other problems. However, in the prior art, there is no reasonable specification for the use of the heat insulating oil pipe.

In view of the above-mentioned technical problems, the inventive concept of the present application is as follows: in order to avoid the various drawbacks existing in mechanical wax removal, starting from the root cause of the wax blocking phenomenon, the inventor found that a thermal insulation oil pipe can be introduced, and only needs to determine the thermal insulation oil pipe. Under the conditions of use, the thermal insulation tubing can be used to reduce the heat loss of the oil flow during the flow of the oil well, thereby avoiding the occurrence of wellbore wax deposition and further avoiding the reduction of productivity.

Hereinafter, the technical solutions of the present application will be described in detail through specific embodiments. It should be noted that the following specific embodiments may be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments.

FIG. 1 is a flowchart of Embodiment 1 of the method for determining the service conditions of an insulated oil pipe provided by the embodiment of the present application. As shown in Figure 1, the determination method may include the following steps:

Step 11: According to the pre-obtained inlet pressure and liquid/gas production, input a preset calculation model respectively to obtain the apparent thermal conductivity of the insulated oil pipe.

Among them, the thermal insulation oil pipe includes: vacuum thermal insulation oil pipe and aerogel thermal insulation oil pipe. This step is described by taking the vacuum insulated oil pipe as an example.

In this step, the inlet pressure and liquid/gas production can be obtained in advance, and then the obtained inlet pressure and liquid/gas production can be input into the preset calculation model respectively to obtain the operating temperature parameters of the insulated oil pipe, Then, the apparent thermal conductivity of the insulated oil pipe is obtained.

Among them, the apparent thermal conductivity of the thermal insulation oil pipe is used to represent the relationship between the thickness of the thermal insulation material and the thermal conductivity, and the calculation model is used to calculate the apparent thermal conductivity of the thermal insulation oil pipe.

In a possible implementation, the inlet pressure can be preset to be 17.2MPa, the bottom-hole flow pressure to be 22.9MPa, the length of the tubing to be 3146m, of which the length of the insulated tubing is 1196m, the depth of the packer to be 2880m, and the gas production to be 40000m 3.d ^{-1 (} 40000 cubic meters per day), the preset calculation model can be a commercial simulator.

Specifically, FIG. 2A is a schematic diagram of a calculation model interface provided by an embodiment of the present application. As shown in Figure 2A, an EKT device can be added at the position where the length of the insulating oil pipe is 1196 m to calculate the apparent heat conductivity of the insulating oil pipe and the total heat transfer coefficient of each layer when the length of the insulating oil pipe is 1196 m. It is worth noting that the length of the tubing can be freely configured, and it can also be the position of 3146m in Figure 2A.

Optionally, in practical applications, the apparent heat conductivity of the insulated tubing is a part of the total heat conductivity of each layer of the wellbore in the oil well, and the total heat transfer coefficient of each layer includes: The apparent thermal conductivity, the thermal conductivity of the outer tube of the insulated tubing, the thermal conductivity of the annulus between the tubing and the production casing, the thermal conductivity of the production casing, and the thermal conductivity of the cement layer.

In a possible implementation, when the length of the insulating oil pipe is 1196 m, the inner diameter of the insulating oil pipe is 50.6 mm, the wall thickness is 4.85 mm, and the thermal conductivity is 56.4 W/m/k; the apparent thickness of the insulating oil pipe is 7.85 mm, the apparent thermal conductivity is 0.02W/m/k; the wall thickness of the outer tube of the insulated tubing is 6.45mm, and the thermal conductivity is 56.4W/m/k; the wall thickness of the annulus between the tubing and the production casing is 14.85 mm, the thermal conductivity varies with temperature, not a fixed value, it needs to be represented by a text file for reading by a commercial simulator; the wall thickness of the production casing is 10.54mm, and the thermal conductivity is 50W/m/k; cement The equivalent wall thickness of the layer is 52.3875mm and the thermal conductivity is 3.5W/m/k.

Specifically, FIG. 2B is a schematic diagram of a variation curve of wellbore flow temperature with depth provided by an embodiment of the present application. As shown in FIG. 2B , the horizontal axis is the flow temperature (° C.), and the vertical axis is the depth (m) down from the wellhead. When the depth is 0m (ie, the wellhead position), the wellhead temperature corresponds to 33°C, which is close to the actual measured value of 33.8°C. Therefore, it can be considered that the obtained apparent thermal conductivity of the insulated tubing is accurate.

Based on the above analysis of the wellbore flow temperature, especially the calibration of the wellhead temperature, it can be seen that the apparent thermal conductivity of the vacuum insulated tubing is 0.02W/m/k, and the apparent heat conductivity of the lined aerogel insulated tubing is 0.021W/ The m/k is similar, in practical application, it should also be compared in terms of mechanical properties, market price, etc.

Optionally, the vacuum insulation oil pipe has good thermal insulation effect, but it is difficult to manufacture and requires high installation size; while the lined aerogel insulation oil pipe has a wide range of applicable temperatures and has good compression and tensile resistance. , Anti-ultraviolet aging and so on. In practical applications, if the topography of the oil field is complex and the geological conditions are prone to change, aerogel-lined thermal insulation tubing can be used as a material to prevent wax blockage in oil wells.

Step 12: According to the apparent thermal conductivity, respectively obtain wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness.

In this step, according to the apparent thermal conductivity, under the conditions of different liquid production rates, the wellhead temperature corresponding to different lengths of the thermal insulation tubing under the set first thermal insulation thickness is obtained.

Wherein, the first thermal insulation thickness may be 9mm. In a possible implementation, FIG. 3 is a schematic diagram of wellhead temperatures corresponding to different tubing lengths when the first thermal insulation thickness is provided in the embodiment of the present application. As shown in Fig. 3, the length of the insulated tubing can be 2000m, 1500m, 1000m, 800m and 500m. With the increase of the liquid production volume/m ³ .d ^-1 , the wellhead temperature/°C also increases.

That is, as the length of the insulated tubing increases, the wellhead temperature also increases. Specifically, when the lengths of the insulated tubing are 2000m, 1500m, 1000m, 800m and 500m, and the liquid production is all 20m ³ .d ^-1 , the corresponding temperatures are about 36°C, 34°C, 31°C, 30°C and 27°C, respectively.

Step 13: According to the apparent thermal conductivity, respectively obtain wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness.

In this step, according to the apparent thermal conductivity, under the conditions of different liquid production rates, the wellhead temperatures corresponding to different lengths of the insulated tubing at the set second thermal insulation thickness are obtained.

Wherein, the second thermal insulation thickness may be 6mm. In a possible implementation, FIG. 4 is a schematic diagram of wellhead temperatures corresponding to different tubing lengths when the second thermal insulation thickness is provided in the embodiment of the present application. As shown in Figure 4, the length of the insulated tubing can be 2000m, 1500m, 1000m, 800m and 500m. With the increase of the liquid production volume/m ³ .d ^-1 , the wellhead temperature/°C also increases.

That is, as the length of the insulated tubing increases, the wellhead temperature also increases. Specifically, when the lengths of the insulated tubing are 2000m, 1500m, 1000m, 800m and 500m, and the liquid production is all 20m ³ .d ^-1 , corresponding to temperatures of about 31°C, 30°C, 29°C, 28°C and 26°C, respectively.

Step 14: Determine the temperature of the thermal insulation tubing according to the wellhead temperatures corresponding to the lengths of the plurality of tubing when the thermal insulation thickness is the first thermal insulation thickness, and the wellhead temperatures corresponding to the lengths of the pipelines when the thermal insulation thickness is the second thermal insulation thickness. Conditions of Use.

In this step, the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness in step 12 correspond to the multiple tubing lengths when the thermal insulation thickness is the second thermal insulation thickness in step 13 The wellhead temperatures were compared with each other, and it was determined that the wellhead temperatures corresponding to multiple tubing lengths were different when the thermal insulation thickness was different.

Optionally, the use conditions of the insulated tubing include the depth range of the oil well. Specifically, under the same output, when the lengths of the insulated tubing are respectively 2000m, 1500m, 1000m, 800m and 500m, the thickness of the insulation of 9mm is greater than that of the insulation of 6mm. The higher the thermal thickness, the higher the wellhead temperature achieved; that is, the thinner the thermal insulation thickness, the lower the wellhead temperature achieved at the same production rate.

In the method for determining the service conditions of the insulated oil pipe provided by the embodiment of the present application, according to the pre-obtained inlet pressure and liquid/gas production volume, a preset calculation model is respectively input to obtain the apparent thermal conductivity of the insulated oil pipe. Based on the apparent thermal conductivity, the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness of the thermal insulation tubing is the first thermal insulation thickness, and the wellhead temperatures when the thermal thermal insulation thickness of the thermal insulation tubing is the second thermal insulation thickness are obtained respectively. The wellhead temperature corresponding to each tubing length. Finally, according to the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness, and the wellhead temperatures corresponding to the multiple tubing lengths when the thermal insulation thickness is the second thermal insulation thickness, the use conditions of the thermal insulation tubing are determined. . In this method, by comparing the thermal insulation tubing with different thermal insulation thicknesses, it is determined that the thicker the thermal insulation thickness and the higher the wellhead temperature, the better the thermal insulation tubing effect will be when the thermal insulation tubing is used in different tubing lengths.

On the basis of the foregoing embodiment, FIG. 5 is a flowchart of Embodiment 2 of the method for determining the service conditions of an insulated oil pipe provided by the embodiment of the present application. As shown in Figure 5, the determination method may further include the following steps:

Step 21 , obtaining the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths.

In this step, in order to better determine the use conditions of the insulated tubing, the wellhead temperature of the insulated tubing and the wellhead temperature of the ordinary tubing are introduced, and it is determined that the wellhead temperature of the insulated tubing is compared with the wellhead temperature of the ordinary tubing. The change value (that is, the temperature increase value).

In a possible implementation, FIG. 6 is a schematic diagram of a mapping relationship of wellhead temperature rise values corresponding to different thermal insulation tubing lengths provided by an embodiment of the present application. As shown in Figure 6, keeping the thermal insulation thickness of the thermal insulation oil pipe unchanged at 9mm, the liquid yields are 20m ³ .d ^-1 , 30m ³ .d ^-1 , 40m ³ .d ^-1 , ^and 50m ³ .d -1 respectively ¹ , 60m ³ .d ^-1 and 70m ³ .d ^-1 . When the lengths of the insulated oil pipes are 2000m, 1500m, 1000m, 800m and 500m respectively, the curves of different temperature rise values show a certain upward trend.

Step 22: Determine the range of the liquid production volume used by the thermal insulation oil pipe according to the mapping relationship.

In this step, the schematic diagram shown in FIG. 6 is analyzed to determine the range of the liquid production volume used by the insulated oil pipe under different lengths of the insulated oil pipe.

In a possible implementation, the use conditions also include the range of liquid production. As can be seen from the above Figure 6, when the length of the insulated tubing is 500 m, with the continuous increase of the liquid production, the change of the wellhead temperature rise does not change. Obviously, when the length of the insulated tubing is 800m, 1000m, 1500m and 2000m respectively, with the continuous increase of the liquid production, the wellhead temperature rises continuously.

Therefore, when the length of the insulating oil pipe is shallow, the effect of the insulating oil pipe is not obvious as the liquid production volume increases.

In the method for determining the service conditions of the insulated oil pipe provided by the embodiment of the present application, by obtaining the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated oil pipe under different lengths of the insulated oil pipe, the insulated oil pipe is determined according to the mapping relationship. The range of liquid yield used. In this method, through the analysis of the temperature rise value of the wellhead under different conditions, it is determined that under different liquid production rates of the insulated tubing, with the increase of the length of the insulated tubing, the higher the wellhead temperature, the more effective the insulated tubing will be. it is good.

On the basis of the foregoing embodiment, FIG. 7 is a flowchart of Embodiment 3 of the method for determining the service conditions of an insulated oil pipe provided by the embodiment of the present application. As shown in Figure 7, the determination method may further include the following steps:

Step 31: For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes smaller than the preset value.

In this step, the thermal insulation oil pipe under extremely low liquid production is analyzed to determine the use conditions of the thermal insulation oil pipe. For different tubing lengths, multiple low-production fluid volumes can be preset, and the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume can be obtained respectively.

In a possible implementation, Table 1 is a comparison table of wellhead temperature at a depth of 2000m between insulated tubing and ordinary tubing under low liquid production. Among them, the thermal insulation thickness of the thermal insulation oil pipe is 9mm.

Table 1:

Step 32: Determine the mapping relationship between the liquid production volume and the wellhead temperature rise value of the thermal insulation tubing according to the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume.

In this step, based on the obtained wellhead temperature of the insulated tubing corresponding to each liquid production volume and the wellhead temperature of the ordinary tubing, the difference between the wellhead temperatures of the insulated tubing and the ordinary tubing under different liquid production volumes is calculated, That is, the wellhead temperature rise value.

In a possible implementation, based on Table 1, Table 2 is a comparison table of wellhead temperature rise values at a depth of 2000m between insulated tubing and ordinary tubing under low fluid production. Among them, the thermal insulation thickness of the thermal insulation oil pipe is 9mm.

Table 2:

Liquid yield/(m³.d^-1) Temperature rise value/℃ 2 1.95 3 2.88 5 4.75 8 7.36 10 8.91

It can be seen from Table 2 that as the liquid production decreases, the difference between the wellhead temperature corresponding to the insulated tubing and the wellhead temperature corresponding to the ordinary tubing is smaller, and the insulated tubing is not suitable for oil wells with extremely low liquid production.

In order to make the use conditions of the insulated tubing more accurate, FIG. 8 is a schematic diagram of the mapping relationship of the wellhead temperature rise value corresponding to the low liquid production volume provided by the embodiment of the present application. As shown in Figure 8, when the length of the insulated tubing is 1500m and 1000m respectively, with the increase of liquid production, the temperature rise value increases, and the temperature rise value of the mapping curve when the length of the tubing is 1500m Greater than the temperature rise value of the mapping curve when the tubing length is 1000m.

However, in Fig. 8, when the liquid production is between 0m ³ .d ^-1 and 5m ³ .d ^-1 , the temperature rise value has no obvious relationship with the length of the insulated tubing, and the two curves basically coincide. Therefore, in The length of the insulated tubing has no effect on the temperature rise when the well production is very low.

According to the method for determining the service conditions of the insulated oil pipe provided by the embodiment of the present application, according to different lengths of the insulated oil pipe, according to a plurality of preset liquid production volumes smaller than the preset value, the insulated oil pipe corresponding to each liquid production volume is obtained respectively. The wellhead temperature and the wellhead temperature of the ordinary tubing, and according to the wellhead temperature of the insulated tubing and the wellhead temperature of the ordinary tubing corresponding to each liquid production volume, determine the mapping between the liquid production volume and the wellhead temperature rise value of the insulated tubing relation. In this method, under the condition of low liquid production, it is determined that the thermal insulation oil pipe is not suitable for oil wells with low liquid production by comparing the length and temperature rise of different insulation oil pipes.

FIG. 9 is a schematic structural diagram of a device for determining the service conditions of an insulated oil pipe according to an embodiment of the present application. As shown in FIG. 9 , the determining apparatus includes: a processing module 41 and a determining module 42 .

The processing module 41 is used to input a preset calculation model according to the pre-acquired inlet pressure and liquid/gas production volume, respectively, to obtain the apparent thermal conductivity of the thermal insulation oil pipe, which is used to represent the thermal insulation thickness and thermal conductivity of the thermal insulation material. The relationship between the capacity, the calculation model is used to calculate the apparent thermal conductivity of the insulated oil pipe;

The processing module 41 is further configured to obtain, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness;

The processing module 41 is further configured to obtain, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness;

The determining module 42 is configured to determine the interval according to the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the first insulation thickness, and the wellhead temperatures corresponding to the plurality of tubing lengths when the insulation thickness is the second insulation thickness. The service conditions of the hot oil pipe, including the depth range of the oil well.

In a possible design of the embodiment of the present application, the processing module 41 is further configured to:

Obtain the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths;

According to the mapping relationship, the used liquid production volume range of the insulated oil pipe is determined, wherein the use conditions also include the liquid production volume range.

In this possible design, the processing module 41 is also used for:

For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes that are less than the preset value;

According to the wellhead temperature of the insulated tubing corresponding to each fluid production volume and the wellhead temperature of the common tubing, the mapping relationship between the liquid production volume and the wellhead temperature rise of the insulated tubing is determined.

Optionally, the thermal insulation oil pipe includes: a vacuum thermal insulation oil pipe and an aerogel thermal insulation oil pipe.

The determining apparatus provided in this embodiment can be used to execute the solutions in the foregoing method embodiments, and the implementation principles and technical effects thereof are similar, and details are not described herein again.

It should be noted that, it should be understood that the division of each module of the above apparatus is only a division of logical functions, and may be fully or partially integrated into a physical entity in actual implementation, or may be physically separated. And these modules can all be implemented in the form of software calling through processing elements; they can also all be implemented in hardware; some modules can also be implemented in the form of calling software through processing elements, and some modules can be implemented in hardware. For example, the determination module may be a separately established processing element, or may be integrated into a certain chip of the above-mentioned device to be implemented, in addition, it may also be stored in the memory of the above-mentioned device in the form of a program code, and a certain processing element of the above-mentioned device may Call and execute the function of the above determined module. The implementation of other modules is similar. In addition, all or part of these modules can be integrated together, and can also be implemented independently. The processing element here may be an integrated circuit with signal processing capability. In the implementation process, each step of the above-mentioned method or each of the above-mentioned modules can be completed by an integrated logic circuit of hardware in the processor element or an instruction in the form of software.

FIG. 10 is a schematic structural diagram of a computer device provided by an embodiment of the present application. As shown in FIG. 10 , the device may include: a processor 51 , a memory 52 and a display 53 .

The processor 51 executes the computer program instructions stored in the memory 52, so that the processor 51 executes the solutions in the above embodiments. The processor 51 can be a general-purpose processor, including a central processing unit CPU, a network processor (NP), etc.; it can also be a digital signal processor DSP, an application-specific integrated circuit ASIC, a field programmable gate array FPGA or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components.

The display 53 may be a user interface, which may be used to display the inlet temperature, etc. in an embodiment, and the user interface may include graphics, text, icons, video, and any combination thereof. Display 53 may also be used to provide virtual buttons and/or a virtual keyboard, also known as soft buttons and/or soft keyboard. In some embodiments, the display 53 may be a front panel of an electronic device; in other embodiments, the display 53 may be a flexible display screen disposed on a curved or folded surface of the electronic device. Even, the display 53 can also be set as a non-rectangular display screen with irregular graphics, that is, a special-shaped screen. The display 53 can be made of materials such as a liquid crystal display (Liquid Crystal Display, LCD), an organic light-emitting diode (Organic Light-Emitting Diode, OLED).

Optionally, the above-mentioned components of the computer equipment may be connected through a system bus.

The computer equipment provided in the embodiments of the present application can be used to execute the solutions in the foregoing embodiments, and the implementation principles and technical effects thereof are similar, and details are not described herein again.

The embodiments of the present application further provide a chip for running instructions, and the chip is used to execute the solutions in the above-mentioned embodiments.

Embodiments of the present application further provide a computer-readable storage medium, where computer instructions are stored in the computer-readable storage medium, and when the computer instructions are executed on a computer, the computer can execute the solutions of the foregoing embodiments.

Embodiments of the present application further provide a computer program product, where the computer program product includes a computer program, which is stored in a computer-readable storage medium, at least one processor can read the computer program from the computer-readable storage medium, and at least one processor The solutions in the above-described embodiments can be implemented when a computer program is executed.

Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, but not to limit them; although the present application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that: It is still possible to modify the technical solutions recorded in the foregoing embodiments, or perform equivalent replacements on some or all of the technical features; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the technical solutions of the embodiments of the present application. scope.

Claims (10)

1. A method for determining the service conditions of an insulated oil pipe, characterized in that, comprising: According to the pre-obtained inlet pressure and liquid/gas production volume, the preset calculation models are respectively input to obtain the apparent thermal conductivity of the insulating oil pipe, where the apparent thermal conductivity is used to represent the difference between the thermal insulating thickness and the thermal conductivity of the thermal insulating material. relationship, the calculation model is used to calculate the apparent thermal conductivity of the insulated oil pipe; According to the apparent thermal conductivity, respectively acquiring the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness; According to the apparent thermal conductivity, respectively acquiring the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness; According to the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness, and the wellhead temperatures corresponding to the plurality of tubing lengths when the thermal insulation thickness is the second thermal insulation thickness, the interval is determined. Conditions of use for hot oil pipes, including the range of depths of oil wells. 2. The method according to claim 1, wherein the method further comprises: Obtain the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths; According to the mapping relationship, a liquid production volume range for use of the insulated oil pipe is determined, wherein the use condition further includes the liquid production volume range. 3. The method according to claim 2, wherein the method further comprises: For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes that are less than the preset value; According to the wellhead temperature of the insulated oil pipe and the wellhead temperature of the common oil pipe corresponding to each liquid production amount, the mapping relationship between the liquid production amount and the wellhead temperature rise value of the insulated oil pipe is determined. 4 . The method according to claim 2 , wherein the thermal insulation oil pipe comprises: a vacuum thermal insulation oil pipe and an aerogel thermal insulation oil pipe. 5 . 5. A device for determining the service conditions of an insulated oil pipe, characterized in that it comprises: a processing module and a determining module; The processing module is configured to respectively input a preset calculation model according to the pre-acquired inlet pressure and liquid/gas production to obtain the apparent thermal conductivity of the insulating oil pipe, where the apparent thermal conductivity is used to represent the thickness of the thermal insulating material The relationship between the thermal conductivity and the thermal conductivity, the calculation model is used to calculate the apparent thermal conductivity of the insulated oil pipe; The processing module is further configured to obtain, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the first thermal insulation thickness; The processing module is further configured to acquire, according to the apparent thermal conductivity, the wellhead temperatures corresponding to the lengths of the plurality of oil pipes when the thermal insulation thickness of the thermal insulation oil pipe is the second thermal insulation thickness; The determining module is used for wellhead temperatures corresponding to a plurality of tubing lengths when the thermal insulation thickness is the first thermal insulation thickness, and a plurality of tubing lengths corresponding to the thermal insulating thickness when the second thermal insulation thickness is the second thermal insulation thickness. The wellhead temperature determines the use conditions of the insulated oil pipe, and the use conditions include the depth range of the oil well. 6. The apparatus according to claim 5, wherein the processing module is further configured to: Obtain the mapping relationship between the liquid production volume and the wellhead temperature rise value of the insulated tubing under different tubing lengths; According to the mapping relationship, a liquid production volume range for use of the insulated oil pipe is determined, wherein the use condition further includes the liquid production volume range. 7. The apparatus according to claim 6, wherein the processing module is further configured to: For different tubing lengths, obtain the wellhead temperature of the insulated tubing and the wellhead temperature of the common tubing corresponding to each fluid production volume according to a plurality of preset liquid production volumes that are less than the preset value; According to the wellhead temperature of the insulated oil pipe and the wellhead temperature of the common oil pipe corresponding to each liquid production amount, the mapping relationship between the liquid production amount and the wellhead temperature rise value of the insulated oil pipe is determined. 8 . The device according to claim 6 , wherein the thermal insulation oil pipe comprises: a vacuum thermal insulation oil pipe and an aerogel thermal insulation oil pipe. 9 . 9. A computer device, comprising: a processor, a memory and a display; the memory stores computer-executable instructions; The processor executes computer-executable instructions stored in the memory, causing the processor to perform the method of any one of claims 1-4. 10. A computer-readable storage medium, wherein computer-executable instructions are stored in the computer-readable storage medium, and when executed by a processor, the computer-executable instructions are used to implement any one of claims 1-4 above. method described in item.

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