Critical liquid carrying model coefficient determination method and device, medium and electronic equipment

Abstract

The invention discloses a critical liquid carrying model coefficient determination method and device, a medium and electronic equipment. The method comprises the following steps: calculating the gas density of a vertical well section in the vertical well section by acquiring the pressure and temperature distribution of the vertical well section in the liquid accumulation period of the gas well; first critical flow rates corresponding to different liquid carrying models are calculated by combining gas well physical property parameters and the vertical well section gas density; and if only one first critical flow velocity is greater than the actual flow velocity, determining a vertical well section liquid carrying model coefficient, and determining an inclined well section liquid carrying model coefficient according to the vertical well section liquid carrying model coefficient. According to the technical scheme provided by the invention, the accuracy of calculating the critical liquid-carrying model coefficient can be improved.

Description

Technical Field

[0001] The present invention belongs to the technical field of oil production engineering, and in particular relates to a method, device, medium and electronic equipment for determining a critical liquid carrying model coefficient. Background Art

[0002] In 1969, Turner first proposed the concept of droplet model with vertical wells as the research object. He believed that the droplets carried by high-speed airflow were spherical. Through the force analysis of spherical droplets, the critical velocity model of gas well liquid carrying was derived. At present, the improvement of the critical liquid carrying droplet model of gas wells is mostly based on the principle of Turner model, and is mainly reflected in the liquid carrying model coefficient. The determination of the liquid carrying model coefficient is mainly based on the following aspects: ① Directly increase or decrease the model liquid carrying coefficient according to the actual gas well data (Coleman model); ② Assume that the shape and size of the droplet are different from the drag coefficient (LiMin model); ③ Consider the correction of the model inclination angle by increasing the inclined well section (Fernando model).

[0003] However, there are still many problems in the study of critical liquid-carrying droplet models for gas wells. First, these models are only applicable to a specific well type (vertical well, inclined well), while for horizontal wells, the entire wellbore structure includes both inclined well sections and vertical well sections, and each well section may affect each other and affect gas liquid carrying, which is not considered by the current liquid-carrying models. Therefore, the Turner formula or other modified formulas cannot be simply used to calculate the critical liquid-carrying flow rate. Furthermore, most liquid-carrying models start from theoretical assumptions and indoor experiments, and the models have certain limitations. For horizontal wells at different engineering sites, the wellbore structures are slightly different, and directly applying the existing liquid-carrying model calculation will be quite different from the actual results.

[0004] Therefore, in view of the above situation, it is necessary to develop a method for determining the critical liquid carrying model coefficient to improve the accuracy of calculating the critical liquid carrying model coefficient. Summary of the invention

[0005] The present invention provides a critical liquid carrying model coefficient determination method, device, medium and electronic equipment. The critical liquid carrying model coefficient determination method provided by the present invention can improve the accuracy of calculating the critical liquid carrying model coefficient.

[0006] Other features and advantages of the present invention will become apparent from the following detailed description, or may be learned in part by the practice of the present invention.

[0007] According to a first aspect of the present invention, a method for determining a critical liquid carrying model coefficient is provided, characterized in that the method comprises: calculating the gas density of the vertical well section in the vertical well section by obtaining the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well; calculating the first critical flow rate corresponding to different liquid carrying models by combining the physical properties of the gas well and the gas density of the vertical well section; if one and only one of the first critical flow rates is greater than the actual flow rate, determining the vertical well section liquid carrying model coefficient, and determining the inclined well section liquid carrying model coefficient based on the vertical well section liquid carrying model coefficient.

[0008] In some embodiments of the present invention, based on the aforementioned scheme, when there are multiple first critical flow rates greater than the actual flow rate, or the first critical flow rates are all less than the actual flow rate, the method further includes: by obtaining the horizontal well inclination point, calculating the inclination point gas density corresponding to the horizontal well inclination point; combining the physical properties of the gas well and the inclination point gas density, calculating the second critical flow rate corresponding to different liquid carrying models, and thereby determining the inclined well section liquid carrying model coefficient according to the second critical flow rate.

[0009] In some embodiments of the present application, based on the aforementioned scheme, before determining the liquid carrying model coefficient of the inclined well section, the method further includes: fitting the second critical flow rate based on the second critical flow rate corresponding to the different liquid carrying models, so as to obtain the liquid carrying model correction coefficient of the inclined well section.

[0010] In some embodiments of the present invention, based on the aforementioned scheme, in the process of determining the liquid carrying model coefficient of the inclined well section, the method also includes: by selecting any point in the inclined well section of the horizontal well, calculating the gas density of the inclined well section corresponding to the any point; calculating the third critical flow rate according to the gas density of the inclined well section and the correction coefficient of the liquid carrying model of the inclined well section; based on the third critical flow rate and the actual flow rate, determining the liquid carrying model coefficient of the inclined well section.

[0011] In some embodiments of the present invention, based on the above scheme, the gas density of the vertical well section is calculated by the following formula:

[0012]

[0013] Among them, γ g is the relative density of gas, P is the pressure, T is the temperature, and Z is the gas deviation coefficient.

[0014] In some embodiments of the present invention, based on the above scheme, the first critical flow rate is calculated by the following formula:

[0015]

[0016] Among them, v c is the critical flow velocity, ρl , g are the liquid and gas phase densities, σ is the gas-liquid interfacial tension, and M is the model coefficient.

[0017] In some embodiments of the present invention, based on the aforementioned scheme, the method further includes: calculating the initial gas density of the inclined well section in the inclined well section by obtaining the pressure and temperature distribution of the inclined well section during the liquid accumulation period of the gas well; calculating the fourth critical flow rate by combining the physical properties of the gas well, the initial gas density of the inclined well section, and the liquid carrying model coefficient of the inclined well section; and verifying the applicability of the liquid carrying model coefficient of the inclined well section based on the fourth critical flow rate and the actual flow rate.

[0018] According to a second aspect of the present invention, a device for determining a critical liquid carrying model coefficient is provided, characterized in that the device comprises: a first calculation unit, used to calculate the gas density of the vertical well section in the vertical well section by acquiring the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well; a second calculation unit, used to calculate the first critical flow rate corresponding to different liquid carrying models in combination with the physical properties of the gas well and the gas density of the vertical well section; a judgment unit, used to determine the vertical well section liquid carrying model coefficient if one and only one of the first critical flow rates is greater than the actual flow rate, and determine the inclined well section liquid carrying model coefficient based on the vertical well section liquid carrying model coefficient.

[0019] According to a third aspect of the present invention, a computer-readable storage medium is provided, wherein at least one program code is stored in the computer-readable storage medium, and the at least one program code is loaded and executed by a processor to implement the operations performed by the described method.

[0020] According to a fourth aspect of the present invention, an electronic device is provided, characterized in that the electronic device includes one or more processors and one or more memories, at least one program code is stored in the one or more memories, and the at least one program code is loaded and executed by the one or more processors to implement the operations performed by the method.

[0021] Compared with the prior art, the present invention has at least the following beneficial effects:

[0022] In order to accurately calculate the critical liquid carrying model coefficient of a horizontal gas well, the present application can divide the horizontal gas well into a vertical well section and an inclined well section during the calculation process. In the vertical well section, the vertical well section gas density in the vertical well section is calculated by obtaining the vertical well section pressure and temperature distribution during the liquid accumulation period of the gas well. Then, based on the calculated vertical well section gas density and the physical property parameters of the gas well, the first critical flow rate corresponding to different liquid carrying models is calculated.

[0023] When there is only one first critical flow rate greater than the actual flow rate, the vertical well section liquid carrying model coefficient can be determined, and the inclined well section liquid carrying model coefficient can be determined according to the vertical well section liquid carrying model coefficient. The liquid carrying model can include Turner liquid carrying model, Coleman liquid carrying model, and LiMin liquid carrying model.

[0024] In the case where there are multiple first critical flow rates greater than the actual flow rate, or the first critical flow rates are all less than the actual flow rate, the horizontal well inclination point is obtained to calculate the inclination point gas density corresponding to the horizontal well inclination point. Then, the second critical flow rate corresponding to different liquid carrying models is calculated by combining the gas well physical property parameters and the inclination point gas density, so as to determine the liquid carrying model coefficient of the inclined well section according to the second critical flow rate.

[0025] Based on this, a critical liquid carrying model coefficient determination method provided by the present invention can improve the accuracy of calculating the critical liquid carrying model coefficient.

[0026] It is to be understood that the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive of the present invention. BRIEF DESCRIPTION OF THE DRAWINGS

[0027] The drawings herein are incorporated into the specification and constitute a part of the specification, showing embodiments consistent with the present invention, and together with the specification, are used to explain the principles of the present invention. Obviously, the drawings described below are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained based on these drawings without creative work. In the drawings:

[0028] Figure 1 A flow chart showing a method for determining a critical liquid carrying model coefficient in an embodiment of the present application is shown;

[0029] Figure 2 A schematic diagram showing a first critical flow rate in an embodiment of the present application is shown;

[0030] Figure 3 A schematic diagram showing the critical flow rate of the Turner liquid carrying model in an embodiment of the present application is shown;

[0031] Figure 4 A schematic diagram showing the critical flow rate of the Coleman liquid carrying model in an embodiment of the present application is shown;

[0032] Figure 5 A schematic diagram showing the critical flow rate of the LiMin liquid carrying model in an embodiment of the present application is shown;

[0033] Figure 6 A schematic diagram showing a third critical flow rate in an embodiment of the present application is shown;

[0034] Figure 7 A schematic diagram showing the gas flow rate in an embodiment of the present application is shown;

[0035] Figure 8 A schematic diagram of the structure of a device for determining a critical liquid carrying model coefficient in an embodiment of the present application is shown;

[0036] Fig. 9 A schematic diagram of the structure of an electronic device in an embodiment of the present application is shown. DETAILED DESCRIPTION

[0037] The following will be combined with the drawings in the embodiments of the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of them. Based on the embodiments in the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0038] In addition, described feature, structure or characteristic can be combined in one or more embodiments in any suitable manner. In the following description, many specific details are provided to provide a full understanding of the embodiments of the present invention. However, it will be appreciated by those skilled in the art that the technical scheme of the present invention can be put into practice without one or more of the specific details, or other methods, components, devices, steps, etc. can be adopted. In other cases, known methods, devices, realizations or operations are not shown or described in detail to avoid blurring the various aspects of the present invention.

[0039] The block diagrams shown in the accompanying drawings are merely functional entities and do not necessarily correspond to physically independent entities. That is, these functional entities may be implemented in software form, or in one or more hardware modules or integrated circuits, or in different networks and / or processor devices and / or microcontroller devices.

[0040] The flowcharts shown in the accompanying drawings are only exemplary and do not necessarily include all the contents and operations / steps, nor must they be executed in the order described. For example, some operations / steps can be decomposed, and some operations / steps can be combined or partially combined, so the actual execution order may change according to actual conditions.

[0041] Next, the present invention application will be described in detail:

[0042] Figure 1The flowchart of the critical liquid carrying model coefficient determination method in the embodiment of the present application is shown. The critical liquid carrying model coefficient determination method can be executed by a device with a computing and processing function, such as a critical liquid carrying model coefficient determination device. Figure 1 As shown, the critical liquid carrying model coefficient determination method includes at least steps 110 to 130, which are described in detail as follows:

[0043] Step 110, calculating the gas density of the vertical well section in the vertical well section by obtaining the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well.

[0044] Step 120, combining the physical property parameters of the gas well and the gas density of the vertical well section, calculates the first critical flow rate corresponding to different liquid carrying models.

[0045] In step 130, if there is only one first critical flow rate greater than the actual flow rate, a vertical well section liquid carrying model coefficient is determined, and a tilted well section liquid carrying model coefficient is determined based on the vertical well section liquid carrying model coefficient.

[0046] In this application, in order to accurately calculate the critical liquid carrying model coefficient of the horizontal gas well, the horizontal gas well can be divided into a vertical well section and a deviated well section during the calculation process. In the vertical well section, the gas density of the vertical well section in the vertical well section is calculated by obtaining the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well.

[0047] Then, according to the calculated gas density of the vertical well section and the physical property parameters of the gas well, the first critical flow rate corresponding to different liquid carrying models is calculated. Among them, the different liquid carrying models include Turner liquid carrying model, Coleman liquid carrying model, and LiMin liquid carrying model. If there is only one first critical flow rate greater than the actual flow rate, the vertical well section liquid carrying model coefficient is determined, and the inclined well section liquid carrying model coefficient is determined according to the vertical well section liquid carrying model coefficient. It should be noted that in one embodiment of the present application, the initial coefficient of the Turner liquid carrying model is 5.5, the initial coefficient of the Coleman liquid carrying model is 4.45, and the initial coefficient of the LiMin liquid carrying model is 2.5.

[0048] Further, in one embodiment of the present application, the gas density of the vertical well section is calculated by the following formula:

[0049]

[0050] Among them, γ g is the relative density of gas, P is the pressure, T is the temperature, and Z is the gas deviation coefficient.

[0051] Further, in one embodiment of the present application, the first critical flow rate is calculated by the following formula:

[0052]

[0053] Among them, v c is the critical flow velocity, ρ l , g are the liquid and gas phase densities, σ is the gas-liquid interfacial tension, and M is the model coefficient.

[0054] In one embodiment of the present application, when there are multiple first critical flow rates greater than the actual flow rate, or the first critical flow rates are all less than the actual flow rate, the process may specifically include steps 141 to 142:

[0055] Step 141, by acquiring the horizontal well inclination point, calculating the inclination point gas density corresponding to the horizontal well inclination point.

[0056] Step 142, combining the physical property parameters of the gas well and the gas density at the deflection point, calculating the second critical flow rate corresponding to different liquid carrying models, and determining the liquid carrying model coefficient of the inclined well section according to the second critical flow rate.

[0057] In the present application, since the first critical flow velocity is greater than the actual flow velocity, or the first critical flow velocity is less than the actual flow velocity, it is necessary to determine the inclined well section liquid carrying model coefficient through the parameters corresponding to the inclined well section, and it cannot be directly calculated through the vertical well section liquid carrying model coefficient.

[0058] Therefore, the gas density of the inclination point corresponding to the horizontal well inclination point can be calculated by obtaining the inclination point of the horizontal well. The inclination point of the horizontal well refers to the intersection of the vertical well section and the inclined well section. Then, according to the obtained inclination point gas density and combined with the physical properties of the gas well, the second critical flow rate corresponding to different liquid carrying models can be calculated, and then the liquid carrying model coefficient of the inclined well section can be determined according to the second critical flow rate.

[0059] In addition, before determining the inclined well section liquid carrying model coefficient, the following step may be further included: based on the second critical flow velocities corresponding to the different liquid carrying models, the second critical flow velocities are fitted to obtain the inclined well section liquid carrying model correction coefficient.

[0060] Furthermore, in the process of fitting the second critical flow velocity, the correction coefficient of the inclined well section liquid carrying model is obtained by the following formula:

[0061]

[0062] Among them, α is the inclination angle of the inclined well section, K d is the correction coefficient of the liquid carrying model in the inclined well section.

[0063] In one embodiment of the present application, in the process of determining the liquid carrying model coefficient of the inclined well section, steps 143 to 145 may be specifically included:

[0064] Step 143, by selecting any point in the inclined well section of the horizontal well, calculate the gas density of the inclined well section corresponding to the any point.

[0065] Step 144, calculating a third critical flow rate according to the gas density of the inclined well section and the correction coefficient of the liquid carrying model of the inclined well section.

[0066] Step 145: Determine the liquid carrying model coefficient of the inclined well section based on the third critical flow rate and the actual flow rate.

[0067] In the present application, after obtaining the correction coefficient of the liquid carrying model of the inclined well section, it is necessary to determine whether the correction coefficient of the liquid carrying model of the inclined well section is the target liquid carrying model coefficient of the inclined well section. Therefore, by selecting any point in the inclined well section of the horizontal well, the gas density of the inclined well section corresponding to the point is calculated, and then the third critical flow rate is calculated according to the gas density of the inclined well section and the correction coefficient of the liquid carrying model of the inclined well section. Then the calculated third critical flow rate is compared with the actual flow rate to determine the liquid carrying model coefficient of the inclined well section. It should be noted that in the process of comparing the third critical flow rate with the actual flow rate, it is necessary to use the principle that there is basically no liquid accumulation at the bottom of the well under the original formation pressure and the applicability of the three liquid carrying model formulas of the vertical well section as the basis for comparison, so that the third critical flow rate can be compared with the actual flow rate more accurately to improve the accuracy of calculating the liquid carrying model coefficient of the inclined well section.

[0068] In one embodiment of the present application, the critical liquid carrying model coefficient determination method further includes steps 146 to 148:

[0069] Step 146, calculating the initial gas density of the inclined well section in the inclined well section by obtaining the pressure and temperature distribution of the inclined well section during the liquid accumulation period of the gas well.

[0070] Step 147, calculating the fourth critical flow rate by combining the physical property parameters of the gas well, the initial gas density of the inclined well section, and the liquid carrying model coefficient of the inclined well section.

[0071] Step 148: Verify the applicability of the liquid carrying model coefficient of the inclined well section based on the fourth critical flow rate and the actual flow rate.

[0072] In the present application, after obtaining the inclined well section liquid carrying model coefficient through the above steps 110 to 145, in order to verify the applicability of the calculated inclined well section liquid carrying model coefficient and each different liquid carrying model coefficient, firstly, the inclined well section pressure and temperature distribution during the gas well liquid accumulation period are obtained to calculate the initial gas density of the inclined well section in the inclined well section. Then, the fourth critical flow rate is calculated by combining the gas well physical property parameters, the initial gas density of the inclined well section, and the inclined well section liquid carrying model coefficient, so as to verify the applicability of the inclined well section liquid carrying model coefficient based on the fourth critical flow rate and the actual flow rate.

[0073] Based on the above steps 110 to 148, a specific embodiment will be described below:

[0074] Taking a horizontal gas well in the Changbei block as an example, the gas density of the vertical well section is calculated when the wellhead pressure is 7.3MPa and the formation pressure decreases to 11.9MPa. Figure 2 , showing a schematic diagram of the first critical flow rate in the embodiment of the present application. By combining the physical property parameters of the gas well and the gas density of the vertical well section, the first critical flow rate corresponding to different liquid carrying models is calculated.

[0075] Then, when there are multiple first critical flow rates greater than the actual flow rate, or the first critical flow rates are all less than the actual flow rate, the wellbore structure trajectory of the gas well begins to deviate horizontally after the vertical depth of 1374m, and the measured depth of 2107m is the inclination point of the well. Therefore, the original formation pressure is 25.4MPa and the wellhead pressure is 1-10MPa respectively, so as to calculate the second critical flow rate of the Turmer liquid carrying model, Coleman liquid carrying model, and LiMin liquid carrying model of the vertical well section.

[0076] Reference Figure 3 , which shows a schematic diagram of the critical flow rate of the Turner liquid carrying model in the embodiment of the present application. Figure 4 , showing a schematic diagram of the critical flow rate of the Coleman liquid carrying model in the embodiment of the present application. Figure 5 , shows a schematic diagram of the critical flow rate of the LiMin liquid-carrying model in the embodiment of the present application. By giving different coefficient values ​​to the invariant liquid-carrying model, the critical flow rate of the Fernando model corresponding to the inclined well section (i.e., the modified model of the liquid-carrying model for the inclined well section) is made equal to at the deflection point, thereby obtaining three Kd values: 0.63, 1.43, and 15.

[0077] Substitute the Kd values ​​calculated above into the Fernando model, and calculate the third critical velocity corresponding to different Kd values ​​in the Fernando model at 25.4MPa, with the wellhead pressure of 1-10MPa, and the bottom depth of the target gas well at about 3436.3m. Figure 6 , showing a schematic diagram of the third critical flow rate in an embodiment of the present application.

[0078] Under the original formation pressure conditions, i.e., at the beginning of the production stage of the gas well, it is basically impossible to produce liquid accumulation, and the actual flow rate at the bottom of the well is less than the critical liquid-carrying flow rate at the bottom of the inclined well section corresponding to the Fernando model when Kd=0.63. Therefore, the critical liquid-carrying model of the inclined well section when Kd=0.63 is not applicable. When the wellhead pressure is greater than 6MPa, the actual gas flow rate at the bottom of the inclined well section is less than the liquid-carrying flow rate at the bottom of the inclined well section corresponding to the Fernando model when Kd=1.43. Although the Coleman model is applicable to gas wells with a wellhead pressure less than 3.45MPa, in the actual production process of the Changbei gas field, the wellhead pressure is greater than 3.45MPa, so the critical liquid-carrying model of the inclined well section when Kd=1.43 is also not applicable. Therefore, the Fernando liquid-carrying model when Kd=15 and the corresponding vertical well section LiMin model are used to calculate the liquid-carrying flow rate of the horizontal well gas well. .

[0079] Reference Figure 7 , showing a schematic diagram of the gas flow rate in the embodiment of the present application. After determining the coefficient of the inclined well section liquid carrying model, the data of the initial liquid accumulation period are taken to verify the applicability of the Fernando liquid carrying model when Kd=15. The liquid carrying model data and the actual gas data of each part of the inclined well section are calculated when the wellhead pressure is 5MPa and the formation pressure decreases to 13.1MPa. It can be obtained that the actual gas flow rate at the bottom of the inclined well section under this condition, that is, at a depth of 3337.9m, is 1.63m / s. The liquid carrying models corresponding to the inclined well section of the Turner liquid carrying model, the Coleman liquid carrying model and the LiMin liquid carrying model calculate the liquid carrying flow rates at this point to be 4.56m / s, 3.72m / s and 2.07m / s respectively. It can be seen that the actual flow rate at the bottom of the inclined well section of the XX-2 well in the initial stage of liquid accumulation is less than the liquid carrying flow rate of the inclined well section liquid carrying model corresponding to the three different Kd values ​​at this point. Due to the initial liquid accumulation stage, the liquid carrying velocity at this point should be closer to the actual flow rate, that is, the critical liquid carrying velocity corresponding to the LiMin liquid carrying model when Kd = 15. The applicability of these two models to this horizontal gas well was verified again.

[0080] Based on the same inventive concept, the present invention also provides a device for determining a critical liquid carrying model coefficient, referring to Figure 8, shows a schematic diagram of the structure of the critical liquid carrying model coefficient determination device in the embodiment of the present application. The critical liquid carrying model coefficient determination device 800 includes: a first calculation unit 801, which is used to calculate the vertical well section gas density in the vertical well section by obtaining the vertical well section pressure and temperature distribution during the gas well liquid accumulation period; a second calculation unit 802, which is used to calculate the first critical flow rate corresponding to different liquid carrying models by combining the gas well physical property parameters and the vertical well section gas density; a judgment unit 803, which is used to determine the vertical well section liquid carrying model coefficient if there is one and only one of the first critical flow rate greater than the actual flow rate, and determine the inclined well section liquid carrying model coefficient according to the vertical well section liquid carrying model coefficient.

[0081] For details not disclosed in the embodiments of the device of the present invention, please refer to the embodiments of the above method of the present invention.

[0082] Based on the same inventive concept, the present application also provides a computer-readable storage medium, characterized in that at least one program code is stored in the computer-readable storage medium, and the at least one program code is loaded and executed by a processor to implement the operations performed by the described method.

[0083] Based on the same inventive concept, the present invention application also provides an electronic device, referring to Fig. 9 , Fig. 9 A schematic diagram of the structure of an electronic device in an embodiment of the present application is shown.

[0084] The electronic device includes one or more memories 904, one or more processors 902, and at least one computer program (program code) stored in the memory 904 and executable on the processor 902. When the processor 902 executes the computer program, the method described above is implemented.

[0085] Among them, Fig. 9 In the embodiment of the present invention, a bus architecture (represented by bus 900) is shown, which may include any number of interconnected buses and bridges, and bus 900 links various circuits including one or more processors represented by processor 902 and memory represented by memory 904. Bus 900 may also link various other circuits such as peripherals, voltage regulators, and power management circuits, which are well known in the art and are therefore not further described herein. Bus interface 905 provides an interface between bus 900 and receiver 901 and transmitter 903. Receiver 901 and transmitter 903 may be the same element, namely a transceiver, providing a unit for communicating with various other devices over a transmission medium. Processor 902 is responsible for managing bus 900 and general processing, while memory 904 may be used to store data used by processor 902 when performing operations.

[0086] The functions described herein may be implemented in hardware, software executed by a processor, firmware, or any combination thereof. If implemented in software executed by a processor, the functions may be stored as one or more instructions or codes on a computer-readable medium or transmitted via a computer-readable medium. Other examples and implementations are within the scope and spirit of the present application and the appended claims. For example, due to the nature of software, the functions described above may be implemented using software executed by a processor, hardware, firmware, hard wiring, or a combination of any of these. In addition, each functional unit may be integrated into a processing unit, each unit may be physically present separately, or two or more units may be integrated into one unit.

[0087] In the several embodiments provided in the present application, it should be understood that the disclosed technical content can be implemented in other ways. Among them, the device embodiments described above are only schematic. For example, the division of the units can be a logical function division. There may be other division methods in actual implementation, such as multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of units or modules, which can be electrical or other forms.

[0088] The units described as separate components may or may not be physically separated, and the components of the control device may or may not be physical units, that is, they may be located in one place or distributed in multiple units. Some or all of the units may be selected according to actual needs to achieve the purpose of the present embodiment.

[0089] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention application is essentially or the part that contributes to the prior art or all or part of the technical solution can be embodied in the form of a software product. The computer software product is stored in a storage medium, including several instructions for a computer device (which can be a personal computer, server or network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present invention application. The aforementioned storage medium includes: U disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), mobile hard disk, magnetic disk or optical disk and other media that can store program codes.

[0090] The above description is only an embodiment of the present invention and is not intended to limit the present invention. For those skilled in the art, the present invention may be modified and varied in various ways. Any modification, equivalent substitution, improvement, etc. made within the spirit and principle of the present invention shall be included in the scope of the claims of the present invention.

Claims

1. A method for determining the coefficients of the critical liquid carrying model, It is characterized in that The method comprises: By obtaining the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well, the gas density of the vertical well section in the vertical well section is calculated; Combining the physical property parameters of the gas well and the gas density of the vertical well section, calculating the first critical flow rate corresponding to different liquid carrying models; If there is only one first critical flow rate greater than the actual flow rate, the vertical well section liquid carrying model coefficient is determined, and the inclined well section liquid carrying model coefficient is determined according to the vertical well section liquid carrying model coefficient.

2. The method according to claim 1, It is characterized in that In the case where there are a plurality of first critical flow rates greater than the actual flow rate, or the first critical flow rates are all less than the actual flow rate, the method further includes: By obtaining the horizontal well inclination point, the inclination point gas density corresponding to the horizontal well inclination point is calculated; The second critical flow rate corresponding to different liquid carrying models is calculated in combination with the physical property parameters of the gas well and the gas density at the deflection point, so as to determine the liquid carrying model coefficient of the inclined well section according to the second critical flow rate.

3. The method according to claim 2, It is characterized in that Before determining the liquid carrying model coefficient of the inclined well section, the method further includes: Based on the second critical flow velocities corresponding to the different liquid carrying models, the second critical flow velocities are fitted to obtain the correction coefficient of the inclined well section liquid carrying model.

4. The method according to claim 3, It is characterized in that In the process of determining the liquid carrying model coefficient of the inclined well section, the method further includes: By selecting any point in the inclined well section of the horizontal well, the gas density of the inclined well section corresponding to the any point is calculated; Calculating a third critical flow rate according to the gas density of the inclined well section and a correction coefficient of a liquid carrying model of the inclined well section; Based on the third critical flow velocity and the actual flow velocity, a liquid carrying model coefficient of the inclined well section is determined.

5. The method according to claim 1, It is characterized in that The gas density of the vertical well section is calculated by the following formula: Among them, γ g is the relative density of gas, P is the pressure, T is the temperature, and Z is the gas deviation coefficient.

6. The method according to claim 1, It is characterized in that The first critical flow rate is calculated by the following formula: Among them, v c is the critical flow velocity, ρ l , g are the liquid and gas phase densities, σ is the gas-liquid interfacial tension, and M is the model coefficient.

7. The method according to claim 1, It is characterized in that The method further comprises: By obtaining the pressure and temperature distribution of the inclined well section during the liquid accumulation period of the gas well, the initial gas density of the inclined well section in the inclined well section is calculated; Calculate the fourth critical flow rate by combining the physical property parameters of the gas well, the initial gas density of the inclined well section, and the liquid carrying model coefficient of the inclined well section; Based on the fourth critical flow velocity and the actual flow velocity, the applicability of the liquid carrying model coefficient of the inclined well section is verified.

8. A device for determining the coefficient of a critical liquid-carrying model, It is characterized in that The device comprises: The first calculation unit is used to calculate the gas density of the vertical well section in the vertical well section by obtaining the pressure and temperature distribution of the vertical well section during the liquid accumulation period of the gas well; A second calculation unit is used to calculate the first critical flow rate corresponding to different liquid carrying models by combining the physical property parameters of the gas well and the gas density of the vertical well section; The judgment unit is used to determine the vertical well section liquid carrying model coefficient if one and only one of the first critical flow rate is greater than the actual flow rate, and determine the inclined well section liquid carrying model coefficient according to the vertical well section liquid carrying model coefficient.

9. A computer-readable storage medium, It is characterized in that The computer-readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the operations performed by the method according to any one of claims 1 to 7.

10. An electronic device, It is characterized in that The electronic device includes one or more processors and one or more memories, wherein the one or more memories store at least one program code, and the at least one program code is loaded and executed by the one or more processors to implement the operations performed by the method according to any one of claims 1 to 7.

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